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# In the pre-Base F 2018 emission estimates, an en ergy efficiency factor was applied to energy

related stationary area sources. The energy effici ency factor was applied along with the growth

factor to account for both growth and changes in energy efficiency. That factor was not applied

to the Base F projections since information s upplied by U.S. EPA related to the CAIR growth

factors indicated that growth values for those ca tegories were derived from U.S. Department of

Energy (DOE) and were felt to account for change s in growth and projected energy efficiency.

For the Base G inventory, these energy effici ency factors were re-instituted and used in

conjunction with EGAS 5.0 growth f actors in a manner identical to that used for the pre-Base F

inventories. The energy effici ency factors were derived from U.S. DOE’s Annual Energy

Outlook report.

One significant difference between the Base F a nd Base G control factors was for counties and

independent cities in northern Virginia. Several counties and i ndependent cities in northern

Virginia are subject to Ozone Transport Commis sion rules. For these counties and independent

cities, controls for portable fuel containers, mobile equipment repair /refinishing, consumer

products, solvent metal cleaning, and the archit ectural and industrial maintenance rules

were added. The counties/independent cities (FI PS code) included in the changes for Base G

were: Alexandria City (51510), Arlington (51013), Fairfax City (51600), Fairfax (51059), Falls

Church City (51610), Fredericksburg City (51630), Loudoun (51107), Manassas City (51683),

Manassas Park City (51685), Prince Willia m County (51153), Spotsylvania (51177), and

Stafford (51179). Not all OTC rules applied to all counties/cities.

2.2.1.2 Stationary area source growth

As indicated above, growth factors for the Ba se F and Base G 2009 and 2018 inventories were

obtained from the U.S. EPA and ar e linear interpolations of the growth factors used for the Clean

Air Interstate Rule (CAIR) projections. The gr owth factors for the CAIR obtained by MACTEC

were developed using a base year of 2001 and provided growth factors for 2010 and 2015.

MACTEC used the TREND function in Micr osoft ExcelTM to calcu late 2002, 2009 and 2018

values from the 2001, 2010 and 2015 values. The TREND function provides a linear

interpolation of intermediate values from a know n series of data points (in this case the 2001,

2010 and 2015 values) based on the equation for a strai ght line. These values were calculated at

the State and SCC level with the excepti on of paved road emissions (SCC = 2294000000). The

growth factors for paved roads were available in the CAIR data set at the State, county and SCC

level so they were applied at that level.

Prior to utilizing the growth factors from th e CAIR projections, MACTEC confirmed that all

SCCs found in the VISTAS 2002 base year inventor y were in the CAIR file (for Base F the

starting point was the version 3.1 2002 base year inventory, for Base G the starting point was the

Base F 2002 base year inventory). Some SCCs were not found in the CAIR file. For those SCCs,

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# the growth factors used were derived in one of five ways. First where po ssible, they were taken

from a beta version of EGAS 5.0. In other cases, the growth factor wa s set to one (i.e., no

growth). In other cases, a similar SCC that had a CAIR growth factor was used. In a few cases a

growth factor based on an average CAIR growth at the 6 digit SCC level was calculated. Finally

a number of records used populati on as the growth surrogate. For the Base G inventory, CAIR

growth factors for fuel fired area sources were replaced with EGAS 5.0 gr owth factors (used in

conjunction with AEO fuel efficien cy factors). A comment field in the growth factor file was

used to mark those records that were not taken di rectly from the CAIR pr ojection growth factors.

2.2.1.3 Differences between 2009/2018

Methodologically, there was no difference in the way that 2009 and 2018 emissions were

calculated for stationary area sources. The indivi dual control and growth factors were different

(due to the linear interpolation used to calculate th e values) but the calculation methods were

identical. This applies to both Base F and Base G.

The only exception to this is for the State of North Carolina for Base G. North Carolina provided

an emissions update file used to override calcu lated projections for a number of area source

categories. The values in thes e files (provided for both 2009 and 2018) were used to overwrite

the calculated projected emi ssions in the final NIF file.

2.2.2 Agricultural area sources

The general approach used to calculate project ed emissions for agricu ltural area sources

(predominantly NH 3 

# emission sources) was as follows:

1. MACTEC used the version 3.1 2002 base year inventory data (which was based on

the CMU ammonia model version 3.6).

2. MACTEC worked with the VISTAS States (via the Agricultural Sources SIWG) to

obtain any State specific growth and/or future controls from the States for agricultural

sources.

3. Since the base year emissions were unc ontrolled, and no future controls for these

sources were identified, MACTEC projecte d the agricultural em issions using Statespecific growth if available, otherwise the U.S. EPA’s Interstate Air Quality

Transport Rule (IAQTR)/Ammonia inventory wa s used to develop the growth factors

used to project the revised 2002 base y ear inventory to 2009 or 2018. Since the

IAQTR inventory was only used to construc t growth factors rather than using the

emissions directly, no updated growth f actors were prepared from the CAIR

inventory values.

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# 4. MACTEC then provided the final draft inventory for review and comment by the

VISTAS States.

No change in the agricultural area source emi ssion projections were made between Base F and

Base G other than the removal of wild animal a nd human perspiration as a result of their removal

from the 2002 base year file for Base G.

2.2.2.1 Control assumptions for agricultural area sources

No controls were identified either by the indi vidual VISTAS States or in the information

provided in the EPA’s IAQTR or CAIR Ammoni a inventory documents. Thus all projected

emissions for agricultural area sources re present simple growth with no controls.

2.2.2.2 Growth assumptions for agr icultural area sources

Growth for several agricultural area source live stock categories was developed using the actual

emission estimates developed by the EPA as part of the NEI. That work included projections for

the years 2002, 2010, 2015, 2020, and 2030. The actual emissions themselves were not used

other than to develop growth factors since th e 2002 NEI upon which the growth projections were

based was prepared prior to th e release of the 2002 Census of Agriculture data which was

included in the CMU model (version 3.6) used to develop the Base F 2002 VISTAS base year

inventory. Thus VISTAS Agricultural Sources SI WG decided to use the NEI ammonia inventory

projected emissions to develop the 2009 and re vised 2018 growth factors used to project

emission for VISTAS. Details on the NEI i nventory and projections can be found at:

http://www.epa.gov/ttn/chief/ap42/c h09/related/nh3inventorydraft_jan2004.pdf . The actual data

files for the projected emissions can be found at:

http://www.epa.gov/ttn/chief/ ap42/ch09/related/nh3output01_23_04.zip

.

In order to use the NEI projected emissions as gr owth factors, several st eps were required. These

steps were as follows:

1. NEI projected emissions were only available for the years 2002, 2010, 2015, 2020,

and 2030, thus the first task was to calculat e intermediate year emissions for 2009 and

2018. These values were calculated based on li near interpolation of the existing data.

2. Once the intermediate emissions were calculated, MACTEC developed emission

ratios to provide growth factors fo r 2009 and 2018. Ratios of emissions were

established relative to the 2002 NEI emissions.

3. Once the growth factors were established, MACTEC then evaluated whether or not

all agricultural SCCs within the revised 2002 base year inventory had corresponding

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# growth factors. MACTEC established that not all SCCs within the base year

inventory had growth factors. These S CCs fell into one of two categories:

b. SCCs that had multiple entries in th e NEI but only a single SCC in the 2002

VISTAS base year inventory. The NEI was established using a process model

and for some categories of animals, em issions were calculated for several

aspects of the process. The CMU mode l version 3.6 which was the basis for

the VISTAS 2002 Base F inventory di d not use a process model. As a

consequence a mapping of SCCs in th e NEI projections and corresponding

SCCs in the CMU inventory was made and for those SCCs an average growth

factor was calculated from the NEI pr ojections for use w ith the corresponding

SCC in the CMU based 2002 Base F inventory.

c. There were also State, county, SCC trios in the 2002 VISTAS Base F

inventory which had no corresponding emi ssions in the NEI files. For these

instances, MACTEC first developed Stat e level average growth factors from

the NEI projections for use in growing these records. Even after developing

State level average growth factors there were still some State/SCC pairs that

did not have matching growth. For these records, MACTEC developed

VISTAS regional average growth factors at the SCC level from the NEI data.

1. Once all of the growth factors were deve loped, they were used to project the

emissions to 2009 and 2018. Growth factors we re first applied at the State, county

and SCC level. Then remaining records we re grown with the State/SCC specific

growth factors. Finally, any remaining ungr own records were projected at the SCC

level using the VISTAS regional growth factor.

For the livestock categories, the NEI emission project ions only had data for beef and dairy cattle,

poultry and swine. Thus for other livestock cate gories and for fertilizers alternative growth

factors were required.

The growth factors for other livestock categorie s and fertilizers were obtained from growth

factors used for the IAQTR projections made by the U.S. EPA. The methodology for these

categories was identical to that used for dairy, beef, poultry and swine with the exception that

State/SCC and VISTAS/SCC growth factors were not required for these categories since the

IAQTR data contained State, c ounty and SCC level growth fact ors. The IAQTR data provided

growth factors for 1996, 2007, 2010, 2015 and 2020. Linear interpolation was used to develop

the growth factors for th e intermediate years 2009 and 2018 required for the

VISTAS projections.

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# There were a few exceptions to the methods used for projecting agricultural sources for the

VISTAS projections. These exceptions were:

1. All swine emissions for North Carolina were maintained at 2002 levels for each

projection year to capture a moratori um on swine production in that State.

2. Ammonia growth factors for a few categories (mainly feedlots) were assigned to be

the same as growth factors for PM emissions from the NEI projections. This

assignment was made because the CMU model showed emissions from these

categories but the NEI projections did not show ammonia emissions but did show PM

emissions.

3. No growth factors were found for horse and pony emissions. These emissions were

held constant at 2002 levels.

There was no change in this method between Ba se F and Base G. Thus Base F and Base G

agricultural emissions are the same in each invent ory. Future efforts on the agricultural emissions

category should look at any changes made to the CMU model to reflect the model farm approach

used by EPA in their inventory plus any updated gr owth factors that may be more recent than the

EPA inventory used to develop gr owth estimates for Base F/G.

2.2.2.2.1 Differences between 2009/2018



# Methodologically, there was no difference in the way that 2009 and 2018 emissions were

calculated for agricultural area sources. The grow th factors were differe nt (due to the linear

interpolation used to calculate the values) but the calculation met hods were identical. In addition

there was no difference between Base F and Base G for this category. Thus Base F and Base G

agricultural emissions are the same in each inventory.

Tables 2.2-1 show the differences between Base F and Base G emissions for all area sources

(including agricultural sources but excluding fires) for the 2 002 base year and 2009 and 2018 by

State and pollutant.

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# Table 2.2-1 2002 Base Year Emissions and Percentage Difference for Base F and Base G

(based on actual emissions).

Actual Area 2002 - Base G

State CO NH3 NOX PM10-PRI PM25-PRI SO2 VOC

AL 83,958 58,318 23,444 393,588 56,654 52,253 182,674

FL 71,079 37,446 28,872 443,346 58,878 40,491 404,302

GA 108,083 80,913 36,142 695,414 103,794 57,559 299,679

KY 66,752 51,135 39,507 233,559 45,453 41,805 95,375

MS 37,905 58,721 4,200 343,377 50,401 771 131,808

NC 345,315 161,860 36,550 280,379 64,052 5,412 237,926

SC 113,714 28,166 19,332 260,858 40,291 12,900 161,000

TN 89,828 34,393 17,844 212,554 42,566 29,917 153,307

VA 155,873 43,905 51,418 237,577 43,989 105,890 174,116

WV 39,546 9,963 12,687 115,346 21,049 11,667 60,443

Base F

AL 83,958 59,486 23,444 393,093 73,352 47,074 196,538

FL 105,849 44,902 29,477 446,821 81,341 40,537 439,019

GA 107,889 84,230 36,105 695,320 133,542 57,555 309,411

KY 66,752 51,097 39,507 233,559 52,765 41,805 100,174

MS 37,905 59,262 4,200 343,377 63,135 771 135,106

NC 373,585 164,467 48,730 303,492 69,663 7,096 346,060

SC 113,714 29,447 19,332 260,858 51,413 12,900 187,466

TN 89,235 35,571 17,829 211,903 49,131 29,897 161,069

VA 155,873 46,221 51,418 237,577 52,271 9,510 129,792

WV 39,546 10,779 12,687 115,346 25,850 11,667 61,490

Percentage Difference (negative values means Base G increased from Base F)

AL 0.00% 1.96% 0.00% -0.13% 22.76% -11.00% 7.05%

FL 32.85% 16.61% 2.05% 0.78% 27.62% 0.12% 7.91%

GA -0.18% 3.94% -0.10% -0.01% 22.28% -0.01% 3.15%

KY 0.00% -0.07% 0.00% 0.00% 13.86% 0.00% 4.79%

MS 0.00% 0.91% 0.00% 0.00% 20.17% 0.00% 2.44%

NC 7.57% 1.59% 24.99% 7.62% 8.05% 23.74% 31.25%

SC 0.00% 4.35% 0.00% 0.00% 21.63% 0.00% 14.12%

TN -0.67% 3.31% -0.09% -0.31% 13.36% -0.07% 4.82%

VA 0.00% 5.01% 0.00% 0.00% 15.84% -1013.45% -34.15%

WV 0.00% 7.57% 0.00% 0.00% 18.57% 0.00% 1.70%

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# Table 2.2-2 2009 Projection Year Emissions and Percentage Difference for Base F and

Base G (based on actual emissions).

Actual Area 2009 - Base G

State CO NH3 NOX PM10-PRI PM25-PRI SO2 VOC

AL 66,654 64,268 23,930 413,020 58,699 48,228 143,454

FL 57,011 38,616 28,187 503,230 64,589 36,699 420,172

GA 94,130 89,212 37,729 776,411 112,001 57,696 272,315

KY 57,887 53,005 42,088 242,177 46,243 43,087 94,042

MS 27,184 63,708 4,249 356,324 51,661 753 124,977

NC 301,163 170,314 39,954 292,443 69,457 5,751 187,769

SC 90,390 30,555 19,360 278,299 41,613 13,051 146,107

TN 74,189 35,253 18,499 226,098 44,124 30,577 154,377

VA 128,132 46,639 52,618 252,488 44,514 105,984 147,034

WV 31,640 10,625 13,439 115,089 20,664 12,284 55,288

Base F

AL 68,882 65,441 26,482 411,614 76,248 17,818 157,405

FL 101,356 46,950 31,821 507,515 90,487 52,390 462,198

GA 103,579 92,838 38,876 776,935 146,691 57,377 294,204

KY 64,806 53,023 42,122 242,345 54,397 40,779 94,253

MS 37,161 64,289 4,789 356,516 65,321 637 125,382

NC 332,443 173,187 53,550 317,847 75,570 7,607 252,553

SC 95,826 31,966 20,852 278,852 54,230 12,945 176,104

TN 82,196 36,578 19,148 225,650 51,753 29,787 160,265

VA 133,738 49,173 53,344 252,924 54,587 10,619 120,022

WV 37,704 11,461 13,816 115,410 25,835 12,156 57,082

Percentage Difference (negative values means Base G increased from Base F)

AL 3.24% 1.79% 9.64% -0.34% 23.02% -170.67% 8.86%

FL 43.75% 17.75% 11.42% 0.84% 28.62% 29.95% 9.09%

GA 9.12% 3.91% 2.95% 0.07% 23.65% -0.56% 7.44%

KY 10.68% 0.03% 0.08% 0.07% 14.99% -5.66% 0.22%

MS 26.85% 0.90% 11.27% 0.05% 20.91% -18.10% 0.32%

NC 9.41% 1.66% 25.39% 7.99% 8.09% 24.41% 25.65%

SC 5.67% 4.41% 7.16% 0.20% 23.27% -0.82% 17.03%

TN 9.74% 3.62% 3.39% -0.20% 14.74% -2.65% 3.67%

VA 4.19% 5.15% 1.36% 0.17% 18.45% -898.09% -22.51%

WV 16.08% 7.29% 2.73% 0.28% 20.02% -1.06% 3.14%

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# Table 2.2-3 2018 Projection Year Emissions and Percentage Difference for Base F and Base

G (based on actual emissions).

Actual Area 2018 - Base G

State CO NH3 NOX PM10-PRI PM25-PRI SO2 VOC

AL 59,626 71,915 25,028 445,256 62,323 50,264 153,577

FL 53,903 40,432 30,708 578,516 72,454 38,317 489,975

GA 93,827 99,885 41,332 880,199 123,704 59,729 319,328

KY 54,865 55,211 44,346 256,052 47,645 44,186 103,490

MS 22,099 69,910 4,483 375,495 53,222 746 140,134

NC 290,809 180,866 43,865 315,294 71,262 6,085 189,591

SC 83,167 33,496 20,592 304,251 44,319 13,457 161,228

TN 68,809 36,291 19,597 246,252 46,692 31,962 182,222

VA 121,690 50,175 56,158 275,351 46,697 109,380 150,919

WV 28,773 11,504 14,828 121,549 21,490 12,849 60,747

Base F

AL 63,773 73,346 28,754 445,168 82,449 49,975 168,507

FL 100,952 49,889 35,047 582,832 101,872 59,413 533,141

GA 105,059 103,911 42,260 880,800 163,925 61,155 342,661

KY 65,297 55,356 45,597 256,544 57,110 42,326 102,117

MS 36,425 70,565 5,230 375,931 68,338 831 139,419

NC 327,871 184,167 60,073 345,275 85,018 8,273 234,207

SC 89,343 35,082 22,467 304,940 58,441 13,517 196,946

TN 81,242 37,812 20,928 245,893 55,712 31,047 188,977

VA 129,037 53,023 56,668 275,790 58,141 11,479 128,160

WV 36,809 12,390 15,079 121,964 27,088 13,450 62,164

Percentage Difference (negative values means Base G increased from Base F)

AL 6.50% 1.95% 12.96% -0.02% 24.41% -0.58% 8.86%

FL 46.61% 18.96% 12.38% 0.74% 28.88% 35.51% 8.10%

GA 10.69% 3.87% 2.20% 0.07% 24.54% 2.33% 6.81%

KY 15.98% 0.26% 2.74% 0.19% 16.57% -4.40% -1.34%

MS 39.33% 0.93% 14.28% 0.12% 22.12% 10.19% -0.51%

NC 11.30% 1.79% 26.98% 8.68% 16.18% 26.45% 19.05%

SC 6.91% 4.52% 8.34% 0.23% 24.16% 0.44% 18.14%

TN 15.30% 4.02% 6.36% -0.15% 16.19% -2.95% 3.57%

VA 5.69% 5.37% 0.90% 0.16% 19.68% -852.83% -17.76%

WV 21.83% 7.15% 1.66% 0.34% 20.66% 4.46% 2.28%



# 2.2.3 Changes to Prescribed Fire for 2009/2018 Base G

Just prior to release of versi on 3.1 of the VISTAS inventory seve ral Federal agencies indicated

that they had plans for increased prescribed fire burning in future years and that the “typical” fire

inventory would likely not adequately capture those increases (memo from Bill Jackson and

Cindy Huber, August 13, 2004). However data were not readily available to incorporate those

changes up through the Base F inventory. As a consequence MACTEC wo rked with Federal

Land Managers to acquire the data necessary to provide 2009 and 2018 specific projections for

the prescribed fire component of the Base G fire invent ory. The 2009 and 2018 projections

developed using the method described below ar e being used by VISTAS as the 2009 and 2018

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# base case inventories for all States except FL. For FL the supplied data from the FLMs is not

being used as FL felt that their data adequately reflected current and fu ture prescribed burning

practices. The “typical” fire projection is the 2002 base prescribed fire projection.

One of the biggest issues in preparing the proj ection was how best to incorporate the data. Two

agencies submitted data: Fish and Wildlife Service (FWS) and Forest Service (FS). FWS

submitted annual acreage data by National Wildlife Refuge (NWR) and county with estimates of

acres burned per day for each NWR. FS provi ded fire-by-fire acreage estimates based on

mapping projected burning acreage to current 2002 modeling days. However, FWS did not

submit data for VISTAS original base year pr eparation process, thus there was no known FWS

data in the 2002 actual or typi cal inventories. Thus MACTEC had to develop a method that

could use the county level data submitted by FWS.

In addition, despite the fact that the FS submitte d fire-by-fire data for the 2002 actual inventory

and had mapped the projections to current bu rn days in the 2002 act ual inventory, MACTEC

could not do a simple replacement of thos e records with the 2009/2018 projections. This

situation was created because several VISTAS St ates run a prescribed fire permitting program.

To avoid double counting, only State data was used in those States for the 2002 actual inventory.

Thus there were no Federal data in those States since the Federal data could have potentially

duplicated State-supplied prescribed fire data. In VISTAS States without permit programs, the

FS supplied data for 2002 was used and those reco rds were marked in database. Thus for those

States, the FS supplied 2009/2018 data could be directly substituted for the 2002 data.

The method used by MACTEC to include the FS da ta applied a county level data approach for

FS data where a State had a prescribed fire pe rmitting program and a fire-by-fire replacement for

FS data in States without permit programs. MACTEC used a county level approach for all of the

FWS data. The approach used for eac h data set is discussed below.

For the FWS data MACTEC summed the annual acres burned supplied by the FWS across all

NWRs in a county. We then subtracted out 2002 acreage for that county from the FWS projected

acreage annual total to avoid double counting. Th e remaining acreage was then multiplied by 0.8

to account for blackened acres instead of the total perimeter acres that were reported. The revised

total additional FWS acreage was then added to th e total county “typical” acreage to determine

future acreage burned for either 2009 or 2018. MA CTEC then allocated th e increased acreage to

current modeling days. The average daily acre s burned data provided by FWS per NWR/county

was used to allocate the acreage to the correct nu mber of days required to burn all of the acres.

Guidance supplied by FWS indicated that up to thr ee times the average daily acres burned could

potentially be allocated to any one day. Thus if the estimated acreage per day were 100 acres

then up to 300 acres could actually be allocated to a particular day. This approach (use of up to

three times the average daily acres burned) was us ed if there were an insufficient number of 2002

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# modeling days available to account for all of the acreage increase. MACTEC used an

incremental approach to using the increase above the base average daily acres. First we used

twice the average daily acreage if that was suffici ent to completely allocate the increased acreage

over the total number of days avai lable. If that wasn’t sufficient then we used three times the

average daily acres burned to allocate the acreag e. We applied the highest increases to days in

the database that already had the highest acr eage burned since we felt those days were most

likely to represent days with representative conditions for conducti ng prescribed burns.

The approach used by MACTEC for the FS was s lightly different. For States that had permit

programs, we used similar approach to the FW S county level approach. First we summed the FS

data at county level, we then added that value to the typical acreage and then we allocated the

acres to current modeling days. The mapping to current modeling days was performed by Bill

Jackson of the USFS and provided to MACTEC. For States that do not have a prescribed fire

permit program, MACTEC simply re placed the current fire-by-fire records in the database with

fire-by-fire records from the FS and recalculated emissions based on fuel model and fuel loading.

We also applied the same 0.8 corr ection for blackened acres applied to all FS supplied acreage as

the supplied values represented perimeter acres.

An additional problem with developing year-specific prescribed fire projections was how to

adequately capture the temporal profile for those fires. In the 2002 actual fire inventory, fires

occur on same days as state/FLM records. In the 2002 “typical” year i nventory, fire acreage

increased or decreased from acreag e on the same fire days as we re in the 2002 actual inventory,

since the acres were simply increased for each day based on a multiplier used to convert from

actual to typical.

When prescribed fires acreage was added to a fu ture year, MACTEC added acreage to individual

fire days proportional to the annual increase (if acreage on a day is 10 percent of annual, add 10

percent of projected incr ease to that same day).

The table below shows how the FWS data for Okefenokee NWR were allocated for 2009 for

Clinch County (Okefenokee NWR is located in f our different counties). You can see that the

total additional acres for the Clinch County portion of Okef enokee NWR was 1,956 acres. Two

hundred eighty (280) acres were the estimated average daily acres burned for that NWR/county

combination. Thus to allocate the entire 1,956 acres would require al most 7 burn days (1,956

divided by 280). However only 5 burn days were found for Clinch County in the 2002 actual fire

database. Thus we allocated twice the average acreage to the burn day with the most acres

burned in the 2002 actual fire da tabase (since our me thod allowed us to increase the average

daily acres burned up to three times the recomm ended level). Thus the first burn day received

560 acres and all others received 280 except the fina l day which received 276 to make the total

equal to the required 1,956 acres. The table also indicates that the increased acres burned

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# 0 2000 4000 6000 8000 10000 12000 14000 16000

1/1/20 02

2/ 1/

20

02

3/1/20 02

4/ 1/

20

02

5/

1/

20

02 6/1/ 20

02

7/1/

20

02 8/1/20 02

9/ 1/

20

02

10/

1/

200

2

11/1/2002

12/1 / 2002



# Date of Fire EventAcres 

# Typical

FWS Add

USFS Add 

# provided increases of from 10-48 percent in the acres burned on th e individual burn days and an

average of approximately 14 percent for the year as a whole.

CLINCH COUNTY 3/1/2002 4/1/2002 2/1/2002 1/1/2002 11/1/2002 12/1/2002 Total

Annual

Acres (typical) 3,757 2,612 1,996 1,801 616 472 11,764

Add on FWS Projection 560 280 280 280 280 276 1,956

Total 4,316 2,891 2,276 2,080 895 747 13,720

Percent Increase 14.9% 10.7% 14.0% 15.6% 45.5% 58.5% 14.3%



# The figure below shows the increases for prescrib ed burning in the four counties that comprise

the Okefenokee NWR area (which also includes FS land). In this figure you can see the

additional acreage added for the burn days from FWS and the individual day increases caused by

projected increases in prescrib ed burning based on FS data. It should be noted that while the

emissions represent 2009, all fire event dates list ed are for 2002 to match up with the base year

meteorology used in modeling exercises.

Table 2.2-4 shows the percentage difference be tween the 2009 and 2018 projections developed

for Base F and Base G. Base G includes the revised prescribed burning estimates described

above. Values are calculated using Base F as the basis for change, thus negative values imply an

increase in emissions for Base G.

Figure 2.2-1 Prescribed Fire Project ion for Okeefenokee NWR for 2009Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesMACTEC, Inc.145Table 2.2-4 Percentage Difference Between BaseF and Base G Fire Emissions by StateStateCONH3NOXPM10-PRIPM25-PRISO2VOCCONH3NOXPM10-PRIPM25-PRISO2VOC2009 Fires Base G2018 Fires Base GAL 534,873 2,050 11,901 52,851 46,543 2,681 27,502 535,658 2,054 11,918 52,927 46,608 2,686 27,539FL 923,310 3,157 19,791 98,470 88,756 4,129 51,527 923,310 3,157 19,791 98,470 88,756 4,129 51,527GA 637,177 2,229 14,243 63,973 57,116 2,914 34,710 637,177 2,229 14,243 63,973 57,116 2,914 34,710KY 31,810 143 682 3,093 2,653 187 1,497 33,296 150 714 3,237 2,777 196 1,567MS 48,160 217 1,033 4,683 4,016 283 2,266 50,037 225 1,073 4,865 4,173 294 2,355NC 96,258 433 2,065 9,359 8,027 566 4,530 111,266 501 2,387 10,819 9,279 655 5,236SC 282,307 1,039 5,899 29,153 25,955 1,359 16,045 282,307 1,039 5,899 29,153 25,955 1,359 16,045TN 17,372 78 373 1,689 1,449 102 817 18,860 85 405 1,834 1,573 111 888VA 21,130 95 453 2,054 1,762 124 994 26,923 121 578 2,618 2,245 158 1,267WV 3,949 18 85 384 329 23 186 5,013 23 108 487 418 29 2362009 Fires Base F2018 Fires Base FAL 514,120 1,957 11,456 50,833 44,812 2,559 26,526 514,120 1,957 11,456 50,833 44,812 2,559 26,526FL 923,310 3,157 19,791 98,470 88,756 4,129 51,527 923,310 3,157 19,791 98,470 88,756 4,129 51,527GA 620,342 2,153 13,882 62,336 55,712 2,815 33,918 620,342 2,153 13,882 62,336 55,712 2,815 33,918KY 56,686 110 1,460 6,667 6,310 136 3,338 56,686 110 1,460 6,667 6,310 136 3,338MS 128,471 177 3,328 14,693 13,680 100 13,625 128,471 177 3,328 14,693 13,680 100 13,625NC 200,564 324 5,005 20,488 19,491 423 12,499 200,564 324 5,005 20,488 19,491 423 12,499SC 253,005 908 5,270 26,304 23,511 1,187 14,666 253,005 908 5,270 26,304 23,511 1,187 14,666TN 78,370 46 2,232 8,875 8,730 59 5,153 78,370 46 2,232 8,875 8,730 59 5,153VA 19,159 159 978 18,160 17,361 99 912 19,159 159 978 18,160 17,361 99 912WV 32,656 12 944 3,276 3,239 16 2,184 32,656 12 944 3,276 3,239 16 2,184Percentage Difference (negative number means an increase in Base G emissions)AL -4.04% -4.77% -3.89% -3.97% -3.86% -4.77% -3.68% -4.19% -4.95% -4.03% -4.12% -4.01% -4.95% -3.82%FL 0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00%0.00% 0.00% 0.00% 0.00% 0.00% 0.00% 0.00%GA -2.71% -3.52% -2.60% -2.63% -2.52% -3.52% -2.34% -2.71% -3.52% -2.60% -2.63% -2.52% -3.52% -2.34%KY 43.88% -29.52% 53.25% 53.61% 57.96% -37.90% 55.15%41.26% -35.57% 51.07% 51.44% 56.00% -44.34% 53.06%MS 62.51% -22.07% 68.95% 68.13% 70.64% -183.85% 83.37%61.05% -26.83% 67.74% 66.89% 69.50% -194.91% 82.72%NC 52.01% -33.75% 58.74% 54.32% 58.82% -33.75% 63.76%44.52% -54.60% 52.31% 47.19% 52.40% -54.60% 58.11%SC -11.58% -14.52% -11.93% -10.83% -10.39% -14.52% -9.40%-11.58% -14.52% -11.93% -10.83% -10.39% -14.52% -9.40%TN 77.83% -69.40% 83.30% 80.97% 83.41% -74.42% 84.14%75.93% -83.92% 81.87% 79.34% 81.98% -89.36% 82.78%VA -10.29% 40.36% 53.67% 88.69% 89.85% -25.40% -9.03%-40.53% 24.00% 40.97% 85.59% 87.07% -59.79% -38.93%WV 87.91% -48.65% 91.03% 88.28% 89.83% -49.46% 91.49%84.65% -88.70% 88.61% 85.12% 87.09% -89.73% 89.20%

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# 2.2.4 Quality Assurance steps

Throughout the inventory developm ent process, quality assuran ce steps were performed to

ensure that no double counting of emissions o ccurred, to ensure that a full and complete

inventory was developed for VISTAS, and to ma ke sure that projecti on calculations were

working correctly. Quality assurance was an impo rtant component to the inventory development

process and MACTEC performed the following QA steps on the stationary and agricultural area

source components of the 2009 and re vised 2018 projection inventories:

1. All final files were run through EPA’s Format and Content checking software.

2. SCC level emission summaries were prepared and evaluated to ensure that emissions

were consistent and that th ere were no missing sources.

3. Tier comparisons (by pollutant) were developed between the 2002 base year

inventory and the 2009 and 2018 projection i nventories. In addition, total VISTAS

pollutant summaries were prepared to co mpare total emissions by pollutant between

versions of the inventory (e.g., between Base F and Base G).

4. Data product summaries were provided to both the VISTAS Emission Inventory

Technical Advisor and to the SIWG repr esentatives for review and comment.

Changes based on these comments were implemented in the files.

5. Version numbering was used for all i nventory files developed. The version

numbering process used a decimal system to track major and minor changes. For

example, a major change would result in a version going from 1.0 to 2.0. A minor

change would cause a version number to go from 1.0 to 1.1. Minor changes resulting

from largely editorial changes would result in a change from 1.00 to 1.01.

2.3 Mobile Sources

Our general approach for assembling data was to use as much existing data from the pre-Base F

preliminary projections as possibl e for these inventories, supple ment these data with easily

available stakeholder input, and provide the results for stakeholder review to ensure credibility.

To develop the “base case” projections, MACTEC originally assembled data to develop two

2009 and 2018 base case inventories: 1) an inventory that incl uded all “on-the-books” control

programs and 2) an “on-the-way” in ventory that included controls th at were likely to be “on-theway”. For the Base F and Base G emission forecas ts to the mobile source sector, “on-the-books”

and “on-the-way” are defined w ith the same strategies and th erefore only a single projection

scenario was developed for each forecast year.

To ensure consistency across evaluation years, the 2009 and 2018 base case inventories were

developed, to the maximum extent practical, usin g methodologies identical to those employed in

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# developing the 2002 on-road portion of the revi sed 2002 VISTAS base year inventory. All

modifications to the 2002 inventory methods were developed in consulta tion with the Mobile

Source Special Interest Workgroup (MSSIWG). Ge nerally, modifications were only made to

properly account for actual change s expected in the interveni ng period (i.e., between 2002 and

2009 and between 2002 and 2018), but the underlyi ng inventory development methodology was

identical, except to the extent re quested by VISTAS or the MSSIWG.

MACTEC developed a preliminary 2018 inventory in early 2004. That inventory was designed

to 1) be used for modeling sensitivity evaluations and 2) help establish the methods that would

be used for the final 2018 inventory and the in itial 2009 inventory. Since that work took place

prior to the revision of the 2002 ba se year inventory data files, MACTEC provided a review of

the data and methods used to develop on-road mo bile source input files for the initial 2002 base

year inventory prior to developing the prel iminary 2018 inventory. Through this review,

MACTEC determined the following:

 

# On-road VMT. Most States provided local da ta for 2002 (or a neighboring year that was

converted to 2002 using appropr iate VMT growth surrogates such as population). Since

these data were not applicable to 2018 due to intervening growth, input for 2018 was

solicited from the MSSIWG. At the same time we researched county-specific growth rate

data utilized for recent national rulemakings as a backstop approach to State supplied

VMT projections.

 

# Modeling Temperatures. Actual 2002 temperat ures were used for the initial 2002 base

year inventory.

 

# Vehicle Registration Mix (age fractions by type of vehicle) . A mix of State, local, and

MOBILE6 default data were used for the 2002 in itial base year inventory. Forecast data

were solicited from the States, with a fallback position that we hold th e fractions constant

at their 2002 values.

 

# Vehicle Speed by Roadway Type. For the 2002 initial base year inventory, speeds

varying by vehicle and road type were used.

 

# VMT Mixes (fraction of VMT by vehicle t ype). A mix of State, local, and quasi

MOBILE6 default (i.e., MOBILE6 defaults normalized to better reflect local conditions)

data were used for the 2002 initial base year inventory. Forecast data were solicited from

the States.

 

# Diesel Sales Fractions. As with the VMT mix data, the diesel sales fraction data

employed for the 2002 initial base year inventory represents a mix of State, local, and

quasi MOBILE6 default data. The issues rela ted to updating these da ta to 2018 are also

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# similar, but are complicated by the fact that MOBILE6 treats diesel sales fraction on a

model year, rather than age specific basis. Therefore, diesel sales fractions generally

cannot be held constant across time. Once ag ain, we solicited any lo cal projections, with

a fallback position that we would keep the da ta for 2002 and earlier model years constant

for the forecast inventory, supplemented w ith MOBILE6 default data for 2003 and newer

model years.

 

# State/Local Fuel Standards. For the 2002 init ial base year inventory, these data were

based on appropriate local requirements a nd updated data for 2018 was only required if

changes were expected between 2002 and 2018. There are some national changes in

required fuel quality for both on-road and non -road fuels that are expected to occur

between 2002 and 2018 and these would be reflec ted in the 2018 invent ory in the absence

of more stringent local fuel controls. Expect ed changes in local fuel control programs

were solicited.

 

# Vehicle Standards. The 2002 initial base ye ar inventory assumed NLEV applicability.

This was altered to reflect Tier 2 for 2018, unless a State indicated a specific plan to

adopt the California LEV II program. If so, we made the required changes to implement

those plans for the preliminary 2018 inventory.

 

# Other Local Controls. This includes vehicle emissions inspection (i.e., I/M) programs,

Stage II vapor recovery programs, anti ta mpering programs, etc. By nature, the

assumptions used for the 2002 initial base ye ar inventory vary acr oss the VISTAS region,

but our presumption is that these data accura tely reflected each State’s situation as it

existed in 2002. If a State had no plans to change program requirements between 2002

and 2018, we proposed to maintain the 2002 program descriptions without change.

However, if a State planned changes, we re quested information on those plans. In the

final implementation of the Base F and ear lier inventories, Stag e II controls were

exercised in the area source component of the inventory, since the units used to develop

Stage II refueling estimates are differe nt between MOBILE6 and the NONROAD

models. However, in the Base G inventories, Stage II refueling was moved to the on-road

and non-road sectors.

Once the preliminary 2018 (pre-Base F) base cas e projection inventor y data were compiled,

MACTEC applied the data and methods selected and proceeded to develop the preliminary (prebase F) base case 2018 projection inventories. Th e resulting inventories were provided to the

MSSIWG in a user-friendly format for review. After stakeholder review and comment, the final

preliminary 2018 base case inventories and input files were provided to VISTAS in formats

identified by the VISTAS Technical Advisor (in this case, MOBILE input files and VMT,

NONROAD input files and annual inventory fi les for NONROAD in NIF 3.0 format). Annual

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# inventory files for MOBILE were not developed as part of this work, only input files and VMT

forecasts. MOBILE emissions were calculated by VISTAS air quality modeling contractor using

the provided files.

2.3.1 Development of on-road mobile source input files

As indicated above, MACTEC prepared a pre liminary version of the 2018 base case mobile

inventory input data files. These files were then updated to provide a fina l set of 2018 base case

inventory input data files as well as a set of i nput files for 2009. The info rmation below describes

the updates performed on the preliminary 2018 files and the development of the 2009 input

data files for Base F emission estimation.

Our default approach to prepar ing the revised 2018 and initial 2009 projection inventories for onroad mobile sources was to estimate the emissions by using either:

1. the revised 2002 data provided by each St ate coupled with the projection methods

employed for the preliminary 2018 inventory, or

2. the same data and methods used to generate the preliminary 2018 inventory.

We also investigated whether or not there wa s more recent VMT forecasting data available (e.g.,

from the CAIR and if appropria te revised the default VMT grow th rates accordingly. This did

not affect any State that pr ovided local VMT forecasting data, but would alter the VMT

estimates used for other areas.

Since no preliminary 2009 inventory was developed there did not exist an option (2) above for

2009. As a consequence, MACTEC crafted the 2009 initial inventory for on-road mobile sources

using methods identical to those employed for th e 2018 preliminary inventor ies coupled with any

changes/revisions provided by the States during the review of th e revised 2002 base year and the

2018 preliminary inventories. Therefore, as was the case for 2018, we obtained from the States

any input data revisions, met hodological revisions, and local cont rol program specifications (to

the extent that they differed from 2002/2018).

2.3.1.1 Preparation of revised 2018 input data files

Preparation of the revised 2018 inventor ies required the following updates:

1. The evaluation year was update d to 2018 in all files.

2. The diesel fuel sulfur content was revised from 500 ppm to 11 ppm, consistent with

EPA data for 2018 in all files.

3. Since the input data is model year, rather than age, specifi c for diesel sales fractions

(with data for the newest 25 model years re quired), we updated all files that included

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# diesel sales fractions. In the revised 2002 base year files, the data included applied to

model years 1978-2002. For 2018, the data incl uded would reflect model years 1994-

2018. To forecast the 2002 data, MACTEC took the data for 1994-2002 from the

2002 files and added data for 2003-2018. To estimate the data for these years, we

employed the assumption employed by "default" in MOBILE6 -- namely that diesel

sales fractions for 1996 and later are consta nt. Therefore, we se t the diesel sales

fractions for 2003-2018 at the same value as 2002.

4. VMT mix fractions must be updated to refl ect expected change s in sales patterns

between 2002 and 2018. If explicit VMT mi x fractions are not provided, these

changes are handled internally by MOBILE6 or externally through absolute VMT

distributions. However, files that include explicit VMT mix fractions override the

default MOBILE6 update and may or may not be consistent with external VMT

distributions. MACTEC upda ted the VMT mix in such files as follows:

First, we calculated the VMT fractio ns for LDV, LDT1, LDT2, HDV, and MC

from the external VMT files for 2018 . This calculation was performed in

accordance with section 5.3.2 of the MOBILE6 Users Guide which indicates:

LDV = LDGV + LDDV

LDT1 = LDGT1 + LDDT

LDT2 = LDGT2

HDV = HDGV + HDDV

MC = MC

The resulting five VMT fractions were then split into the 16 fractions required by

MOBILE6 using the distributions fo r 2018 provided in Appendix D of the

MOBILE6 Users Guide. This approach ensures that explic it input file VMT

fractions are consistent with the absolute VMT di stributions prepared by

MACTEC. These changes were made to all files that included VMT mixes.

5. All other input data were re tained at 2002 values, except as otherwise instructed by

the States. This includes all control pr ogram descriptions (I/M, Anti-Tampering

Program [ATP], Stage II, etc.), all other fu el qualities (RVP, oxy content, etc.), all

other vehicle descriptive data (registrations age distributions, etc.), and all scenario

descriptive data. The Stat e-specific updates performe d are described below.

Kentucky:

MACTEC revised the 2018 input files for the Lo uisville, Kentucky area (Louisville Air Pollution

Control District [APCD]) based on comments received relative to several components of

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# MOBILE input data. Based on these comments, the input files for Jefferson County, Kentucky

were updated accordingly as follows:

a) I/M and tampering program definitions were removed since the program was

discontinued at the end of 2003.

b) The "Speed VMT", "Facility VM T" and "Registration Age Di stribution" file pointers

were updated to reflect revised 2002 file s provided by the Louisville APCD.

c) The "VMT Mix" data, which was previous ly based on the default approach of

"growing" 2002 data, was replaced by 2018-sp ecific data provided by the Louisville

APCD.

North Carolina:

North Carolina provided a wide range of revise d input data, including co mplete MOBILE6 input

files for July modeling. MACTEC did not use the provided input files dir ectly as they did not

match the 2002 NC input files for critical elem ents such as temperat ure distributions and

gasoline RVP (while they were close, they were slightly different). To maintain continuity

between 2002 and 2018 modeling, MA CTEC instead elected to revise the 2002 input files to

reflect all control program a nd vehicle-related changes imp lied by the new 2018 files, while

retaining the basic temperature and gasoline RVP assumptions at their 2002 values. Under this

approach, the following changes were made:

a) NC provided a county cross reference file specific to 2018 that differed from that

used for 2002. We removed files that were referenced in the 2002 input data and

replaced those files with t hose referenced in the 2018 data . In addition, since NC only

provided 2018 input files for July, we estima ted the basic data for these new files for

the other months by cross referencing the target files for 2002 by county against the

target files for 2018 by county.

b) We then revised the 2002 version of each i nput file to reflect the 2018 "header" data

included in the NC-provided 2018 files. Thes e data are exclusivel y limited to I/M and

ATP program descriptions, so that the 2002 I/M and ATP da ta were replaced with

2018 I/M and ATP data.

c) We retained the registration age fractions at their 2002 "value s" (external file

pointers) as per NC instructions.

d) We retained all scenario-specific data (i.e ., temperatures, RVP, etc.) at 2002 values,

which (as indicated above), we re slightly different in most cases from data included

in the 2018 files provided by NC. We believe these differences were due to small

deviations between the data assembled to support VISTAS 2002 and the process used

to generate the 2018 files provided by NC, and that revising the VISTAS 2002 data to

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# reflect these variations was not appropriate given the resu lting inconsistencies that

would be reflected between VISTAS 2002 and VISTAS 2018.

e) NC also provided non-I/M versions of the 2018 input files that would generally be

used to model the non-I/M portion of VMT. Wh ile these files were retained they were

not used for the 2018 input data preparation.

Finally, NC also provided a speed profile file and a speed prof ile cross reference file for 2018.

We did not use these in our updates as they ha ve no bearing on the MOBILE6 input files, but

they were maintained in case they needed to be included in SMOKE control files for a future

year control strategy scenario.

Virginia:

In accordance with instructions from VA, the i nput files that referenced an external I/M

descriptive program file (VAIM02.I M) were revised to reference an alternative external file

(VAIM05.IM). This change was to make the I/ M program more relevant to the year 2018.

One additional important difference was made with respect to the revised 2018 and initial 2009

on-road mobile source input data files for all States. MACTEC developed updated SMOKE

ready input files rather than MOBILE6 files so th at the input data could be used directly by the

VISTAS modeling contractor to estimate on-road mobile source emissions during modeling runs.

2.3.1.2 Preparation of initial 2009 input data files

The methodology used to develop the 2009 on-ro ad input files was based on forecasting the

previously developed revised 2002 base year input files and is identical to that previously

described for the revised 2018 me thodology except as follows:

1. The evaluation year was updated to 2009.

2. Diesel fuel sulfur content was revised from 500 ppm to 29 ppm. The 29 ppm value

was derived from an EPA report entitled "Summary and Analysis of the Highway

Diesel Fuel 2003 Pre-compliance Re ports" (EPA420-R-03-013, October 2003),

which includes the Agency's estimates for the year-to-year fuel volumes associated

with the transition from 500 ppm to 15 ppm di esel fuel. According to Table 2 of the

report, there will be 2,922,284 barrels per da y of 15 ppm diesel distributed in 2009

along with 110,488 barrels per day of 500 ppm diesel. Treating the 15 ppm diesel as

11 ppm on average (consistent with EPA a ssumptions and assumptions employed for

the 2018 input files) and sales weighting the two sulfur content fuels results in an

average 2009 diesel fuel sulfur content estimate of 29 ppm.

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# 3. Diesel sales fractions were updated identic ally to 2018 except that the diesel sales

fractions for 2003-2009 were set at the same value as those for 2002 (rather than

2003-2018).

4. VMT mix fractions were updated to 2009 using an identical method to that described

for 2018.

5. All other input data were re tained at 2002 values, except as otherwise instructed by

individual States (see below). This incl udes all control program descriptions (I/M,

ATP, Stage II, etc.), all othe r fuel qualities (RVP, oxy conten t, etc.), all other vehicle

descriptive data (registration age distributions, etc.), and a ll scenario descriptive data.

In addition to the updates described above that were applied to all VISTAS-region inputs, the

following additional State-specific updates were performed:

KY – Identical changes to those made for 2018 ( but specific to 2009) were made for the

2009 input files.

NC – Identical changes to those made for 2018 ( but specific to 2009) were made for the 2009

input files.

VA – Identical changes to those made for 2018 were made for 2009.

2.3.2 VMT Data

The basic methodology used to generate the 200 9 and 2018 VMT for use in estimating on-road

mobile source emissions was as follows:

1. All estimates start from the final VMT estim ates used for the 2002 revised base year

inventory.

2. Initial 2009 and 2018 VMT estimates were based on linear growth rates for each

State, county, and vehicle t ype as derived from the VMT data assembled by the U.S.

EPA for their most recent HDD (heavy duty diesel) rulemaking. The methodology

used to derive the growth factors is iden tical to that employed for the preliminary

2018 VMT estimates (which is desc ribed in the next section).

3. For States that provided no independent for ecast data, the estimates derived in step 2

are also the final estimates. These States are: Alabama, Florid a, Georgia, Kentucky,

Mississippi, and West Virginia. For States that provided forecast data, the provided

data were used to either replace or augm ent the forecast data based on the HDD rule.

These States, and the specific approaches employed, are detailed following the

growth method description.

The steps involved in performing the grow th estimates for VMT were as follows:

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# 1. Linear growth estimates were used (alt hough MACTEC investigated the potential use

of nonlinear factors and pres ented that information to the MSSIWG, the decision was

made to use linear growth factors instead of nonlinear).

2. Estimates were developed at the vehicl e class (i.e., LDGV, LDGT1, LDGT2, etc.)

level of detail since the base year 2002 estimates were pr esented at that level of

resolution. In effect, the count y and vehicle class specific growth factors were applied

to the 2002 VMT estimates for each vehicle and road class.

3. Overall county-specific VMT estimates fo r each year (developed by summing the

vehicle and road class specific forecasts) were then compared to overall countyspecific growth. Since overall county growth is a more appropriate controlling factor

as it includes the combined impacts of all vehicle classes, the initial year-specific

vehicle and road class VMT forecasts were normalized so that they matched the

overall county VMT growth. Mathemati cally, this process is as follows:

(Est_rv_f) = (Est_rv_i) * (C_20XX / Sum(Est_rv_i))

where:

Est_rv_f = the final road/vehicle class-specific estimates,

Est_rv_i = the initial road/vehicle class-specific estimates, and

C_20XX = the county-specific growth target for year 20XX.

Table 2.3-1 presents a basic summary of the fo recasts for the preliminary 2018 inventory for

illustrative purposes:

Table 2.3-1 2002 versus 2018 VMT (million miles per year)

State 2002 2018 Growth Factor

Alabama 55,723 72,966 1.309

Florida 178,681 258,191 1.445

Georgia 106,785 148,269 1.388

Kentucky 51,020 66,300 1.299

Mississippi 36,278 46,996 1.295

North Carolina 80,166 110,365 1.377

South Carolina 47,074 63,880 1.357

Tennessee 68,316 91,647 1.342

Virginia 76,566 102,971 1.345

West Virginia 19,544 24,891 1.274

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# The following States provided some types of forecast data for VMT. The information presented

below indicates how those data were processed by MACTEC for use in the VISTAS projection

inventories.

Kentucky:

Revised 2009 and 2018 VMT mix data were provid ed by the Louisville APCD. Therefore, the

distribution of Jefferson County VMT by vehicle type within th e KY VMT file was revised to

reflect the provided mix. This did not affect the total forecasted VMT for either Jefferson County

or the State, but does alter th e fraction of that VMT accumulate d by each of the eight vehicle

types reflected in the VMT file. The follo wing procedure was employed to make the

VMT estimates consistent with the provided 2009/2018 VMT mix:

a) The 16 MOBILE6 VMT mix fractions were aggr egated into the following five vehicle

types: LDV, LDT1, LDT2, HDV, and MC.

b) The 8 VMT mileage classes were aggregated into the same five vehicle types (across all

roadway types) and converted to fractions by normalizing against the total Jefferson

County VMT.

c) The ratio of the "desired" VMT fraction (i.e ., that provided in th e Louisville APCD VMT

mix) to the "forecasted" VMT fraction (i.e., that calculated on the basis of the forecasted

VMT data) was calculated for each of the five vehicle classes.

d) All forecasted VMT data for Jefferson County were multiplied by the applicable ratio

from step c as follows:

new LDGV = old LDGV * LDV ratio

new LDGT1 = old LDGT1 * LDT1 ratio

new LDGT2 = old LDGT2 * LDT2 ratio

new HDGV = old HDGV * HDV ratio

new LDDV = old LDDV * LDV ratio

new LDDT = old LDDT * LDT1 ratio

new HDDV = old HDDV * HDV ratio

new MC = old MC * MC ratio

The total forecasted VMT for Jefferson County was then checked to ensure that it was

unchanged.

North Carolina:

North Carolina provided both VMT and VMT mi x data by county and roadway type for 2018.

Therefore, these data replaced the data deve loped for North Carolina using HDD rule growth

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# rates in their entirety. Similar data were s ubmitted for 2009. Table 2.3-2 presents the resulting

VMT estimates which differ from the "default" HDD rule estimates as follows:

Table 2.3-2 VMT and HDD Rule Estimates for North Carolina (million miles per year)

North Carolina

2002 106,795

State Data HDD Data

2009 123,396 124,626

2018 129,552 146,989



# As indicated, there are substantial reductions in the State-provided forecast data relative to that

derived from the HDD rule. The growth rates for both 2009 and 2018 are only about half that

implied by the HDD data (1.15 versus 1.17 for 2009 and 1.21 versus 1.38 for 2018). The

resulting growth rates are the lowest in the VISTAS region.

NC did not provide VMT mix data for 2009. Theref ore, the VMT mix fractions estimated using

the "default" HDD rule growth rates were appl ied to the State-provided VMT estimates to

generate vehicle-specific VMT. Essen tially, the default HDD methodology produces VMT

estimates at the county-road type -vehicle type level of detail, and these data can be converted

into VMT fractions at that same level of deta il. Note that these are not HDD VMT fractions, but

VMT fractions developed from 2002 NC data us ing HDD vehicle-specific growth rates. In

effect, they are 2002 NC VMT fractions "grown" to 2009.

The default VMT mix fraction was applied to th e State-provided VMT data at the county and

road type level of detail to ge nerate VMT data at the county-ro ad type-vehicle type level of

detail. The one exception was for county 063, road 110, for which no VMT data were included in

the HDD rule. For this single county/road comb ination, State-aggregate VMT mix fractions

(using the HDD growth methodology) were applied to the county/road VMT data. The difference

between road 110 VMT fractions across all NC c ounties is minimal, so there is no effective

difference in utilizing this more aggregate appr oach vis-à-vis the more resolved county/road

approach.

South Carolina:

South Carolina provided county and roadway type-s pecific VMT data for several future years.

Data for 2018 was included and was used directly. Data for 2009 was not included, but was

linearly interpolated from data provided for 2007 and 2010. The data were disaggregated into

vehicle type-specific VMT using the VMT mixe s developed for South Carolina using the HDD

rule VMT growth rates. Table 2.3-3 presents th e resulting VMT estimates which differ from the

"default" HDD rule estimates as follows:

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# Table 2.3-3 VMT and HDD Rule Estimates for South Carolina (million miles per year)

South Carolina

2002 47,074

State Data HDD Data

2009 55,147 54,543

2018 65,133 63,880



# Tennessee:

In general, Tennessee estimates are based on the HDD rule growth rate as described in step two.

However, Knox County provided independent VMT estimates for 2018 and these were used in

place of the HDD rule-derived estimates. The Knox County estimates were total county VMT

data only, so these were disaggregated into roadway and vehicle-type VMT using the

distributions developed for Knox County in step two using the HDD rule VMT growth rates. No

data for Knox County were provided for 2009, so the estimates derived using the HDD rule

growth factors were adjust ed by the ratio of "Knox County provided 2018 VMT" to "Knox

County HDD Rule-derived 2018 VMT." Table 2.3-4 presents the resulting VMT estimates which

differ from the "default" HDD rule estimates as follows:

Table 2.3-4 VMT and HDD Rule Estimates for Tennessee (million miles per year)

Tennessee

2002 68,316

State Data HDD Data

2009 78,615 78,813

2018 91,417 91,647



# Virginia:

Virginia provided county and roadway type-spe cific annual VMT growth rates and these data

were applied to Virginia -provided VMT da ta for 2002 to estimate VMT in both 2009 and 2018.

Virginia provided VMT mix data for 2002, but not 2009 or 2018. Therefore, the estimated VMT

data for both 2009 and 2018 were disaggregated in to vehicle type-specific VMT using the VMT

mixes developed for VA using the HDD rule VM T growth rates. Table 2.3-5 presents the

resulting VMT estimates which differ from the "default" HDD rule estimates as follows:

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# Table 2.3-5 VMT and HDD Rule Estimates for Virginia (million miles per year)

Virginia

2002 77,472

State Data HDD Data

2009 88,419 89,196

2018 104,944 104,164



# 2.3.3 Base G Revisions

For the development of the VISTAS 2009 and 2018 Ba se G inventories and input files, VISTAS

states reviewed the Base F inputs, and provide d corrections, updates and supplemental data as

noted below.

For all states modeled, th e Base G updates include:

 

# Adding Stage II refueling emissions cal culations to the SMOKE processing.

 

# Revised the HDD compliance. (REBUILD EFFECTS = .1)

 

# Revised Diesel sulfur values in 2009 to 43 ppm and 2018 to 11 ppm

In addition to the global changes, individual VISTAS states made the following updates:

KY – updated VMT and M6 input values for selected counties

NC – revised VMT estimates, speeds and ve hicle distributions and updated registration

distributions for Mobile 6.

TN - revised VMT and vehicle registrati on distributions for selected counties.

WV – revised VMT input data

AL, FL, and GA and VA did not provide update s for 2009/2018 Base G, and the Base F inputs

were used for these States.

2.3.4 Development of non-road emission estimates

The sections that follow descri be the projection process used to develop 2009 and 2018 non-road

projection estimates, as revised through the sp ring of 2006, for sources found in the NONROAD

model and those sources estimated outside of th e model (locomotives, ai rplanes and commercial

marine vessels).

2.3.4.1 NONROAD model sources

NONROAD model input files were prepared in both the fall of 2004 (Base F) and the spring of

2006 (Base G) based on the corresponding 2002 base ye ar inventory input f iles available at the

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# time the forecasts were developed, with appropria te updates for the projection years. Generally,

this means that the Base F 2002 base year inpu t files (as updated through the fall of 2004) were

used as the basis for Base F projection year i nput file development and Base G 2002 base year

input files as updated through the spring of 2006 were used as the basis for Base G projection

year input file development. Thus , all base year revisions are i nherently incorporated into the

associated projection year re visions. Other specific updates for the projection years for

NONROAD model sources consist of:

1. Revise the emission inventory year in th e model (as well as various output file

naming commands) to be reflec tive of the projection year.

2. Revise the fuel sulfur content for ga soline and diesel powered equipment.

3. Implement a limited number of local cont rol program charges (national control

program changes are handled internally within the NONROAD model, so explicit

input file changes are not required).

All equipment population growth an d fleet turnover impacts are al so handled internally within

the NONROAD model, so that explicit chan ges input file changes are not required.

Base F Input File Changes:

To correctly account for diesel fuel sulfur cont ent differences between the base and projection

years, two sets of input and out put files were prepared for each forecast year, one set for landbased equipment and one set for marine equipm ent. This two-step projection process was

required for Base F, because diesel fuel sulf ur contents varied between land-based and

marine-based non-road equipment and the Dr aft NONROAD2004 used for Base F allowed only

a single diesel fuel sulfur input. Thus, the m odel was executed separately for land-based and

marine-based equipment for Base F, and the a ssociated outputs subsequently combined. The

specific diesel fuel sulfur cont ents modeled were as follows:

Diesel S (ppm) 2002 2009 2018

Land-Based 2500 348 11

Marine-Based 2500 408 56

As indicated, the Draft NONROAD2004 model was run with both sets of input files and the

output file results were then combined to produce a single NONROAD output set.

To correctly account for the national reduction in gasoline sulfur content (a national control not

explicitly handled by the NONROAD model) , all NONROAD input files for both 2009 and 2018

were revised to reflect a gasoline fuel sulfur content of 30 ppmW.

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# Base G Input File Changes:

With the release of Final NONROAD2005 that was used for the Base G projection year

inventory development, the NONROAD model is capab le of handling separate diesel fuel sulfur

inputs for land-based and marine-based non-ro ad equipment in a single model execution.

Therefore, the two step modeling process desc ribed above for Base F updates was no longer

required. Instead, the differential diesel fuel sulfur values are assembled into a single

NONROAD input file as follows:

Diesel S (ppm) 2002 2009 2018

Land-Based 2500 348 11

Marine-Based 2638 408 56

Additionally, revised gasoline vapo r pressure data were provided by Georgia regulators for 20

counties 5 

# where reduced volatility requirements were established in 2003. Since this requirement

began after the 2002 base year, the vapor pressure values in the base year input files for these

counties are not correct for ei ther the 2009 or 2018 forecast year s. Therefore, to correctly

forecast emissions in these counties, the forecas t year gasoline vapor pressure inputs were

revised to:

Gasoline RVP (psi) 2002 2009 2018

Spring 9.87 9.2 9.2

Summer 9.0 7.0 7.0

Fall 9.87 9.2 9.2

Winter 12.5 12.5 12.5

The summer vapor pressure was simply set equal to the 2003 control value, while the spring and

fall vapor pressures were adjusted to reflect a single month of the reduced volatility limit. The

winter volatility was assumed to be unaff ected by the summertime control requirement.

2.3.4.1.1 Differences between 2009/2018



# Other than diesel fuel sulfur content and the ye ar of the projections, th ere are no differences in

the methodology used to estimate emissions fr om NONROAD model sources. As indicated

above, however the Base F 2009/2018 projections were developed us ing Draft NONROAD2004,

while the Base G 2009/2018 projections were made using Final NONROAD2005.

5 

# The specific counties are: Banks, Chattooga, Clarke, Floyd, Gordon, Heard, Jasper, Jones, Lamar, Lumpkin,

Madison, Meriwether, Monroe, Morgan, Oconee, Pike, Polk, Putnam, Troup, and Upson.

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# 2.3.4.2 Non-NONROAD model sources

Using the 2002 base year emissions inventory fo r aircraft, locomotives, and commercial marine

vessels (CMV) prepared as de scribed earlier in this doc ument, corresponding emission

projections for 2009 and 2018 were de veloped in both the fall of 2004 (Base F) and the spring of

2006 (Base G). This section describes the procedur es employed in developing those inventories.

The information presented is intended to build off of that presented in th e section describing the

2002 Base F base year inventory. It should be r ecognized that for both the Base F and Base G

inventories, the base year inventory used to develop the emission forecasts was the latest

available at the time of forecast development. Generally, this means that the 2002 base year

inventory as updated through the fall of 2004 was used as the basis for the Base F projection year

inventory development, and the Base F 2002 base y ear inventory was used as the basis for Base

G projection year inventory development. Thus, a ll base year revisions (a s described earlier in

this document) are inherently incorporated in to the associated proj ection year revisions.

Base F Revisions:

Table 2.3-6 shows the 2002 base year emissions fo r each State in the VISTAS region for aircraft,

locomotives and CMV (as they existed prior to Base F development).

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# Table 2.3-6 Pre-Base F 2002 Aircraft, Locomotive, and Non-Recreational

Marine Emissions

(annual tons, as of the fall of 2004)

Source State CO NO

x 

# PM 10 

# PM 2.5 

# SO 2 

# VOC

AL 3,787 175 226 87 17 196

FL 25,431 8,891 2,424 2,375 800 3,658

GA 6,620 5,372 1,475 1,446 451 443

KY 2,666 657 179 175 63 263

MS 1,593 140 44 43 13 96

NC 6,088 1,548 419 411 148 613

SC 6,505 515 409 401 88 863

TN 7,251 2,766 734 719 235 943

VA 9,763 2,756 1,137 1,115 786 2,529

WV 1,178 78 25 24 8 66 Aircraft

(2275)

Total 70,882 22,899 7,072 6,797 2,607 9,670

AL 1,196 9,218 917 844 3,337 737

FL 5,888 44,817 1,936 1,781 6,683 1,409

GA 1,038 7,875 334 307 1,173 246

KY 6,607 50,267 2,246 2,066 9,608 1,569

MS 5,688 43,233 1,903 1,751 7,719 1,351

NC 599 4,547 193 178 690 142

SC 1,067 8,100 343 316 1,205 253

TN 3,624 27,555 1,217 1,120 4,974 860

VA 972 2,775 334 307 359 483

WV 1,528 11,586 487 448 525 362 Commercial

Marine

(2280)

Total 28,207 209,972 9,911 9,118 36,275 7,413

VA 110 313 25 23 27 48 Military Marine

(2283) Total 110 313 25 23 27 48

AL 3,490 26,339 592 533 1,446 1,354

FL 1,006 9,969 247 222 605 404

GA 2,654 26,733 664 598 1,622 1,059

KY 2,166 21,811 542 488 1,321 867

MS 2,302 23,267 578 520 1,429 899

NC 1,638 16,502 410 369 1,001 654

SC 1,160 11,690 291 261 710 462

TN 2,626 25,627 633 570 1,439 1,041

VA 1,186 11,882 1,529 1,375 3,641 492

WV 1,311 13,224 329 296 808 517 Locomotives

(2285)

Total 19,540 187,044 5,815 5,232 14,022 7,750

Grand Total 118,739 420,228 22,823 21,170 52,931 24,881

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# Although some of the data utilized was updated, the methodology used to develop the Base F

2009 and 2018 emissions forecasts for aircraft, loco motives, and CMV is identical to that used

earlier to develop preliminar y 2018 Base 1 (“On the Books”) and 2018 Base 2 (“On the Way”)

inventories. Briefly, the met hodology relies on growth and cont rol factors developed from

inventories used in support of recent EPA rule makings, and consists of the following steps:

(a) Begin with the 2002 base year emission estimates for aircraft, locomotive, and CMV as

described above (at the State-county- SCC-pollutant level of detail).

(b) Detailed inventory data (both before and after controls) for these same emission sources

for 1996, 2010, 2015, and 2020 were obtained from the EPA's Clean Air Interstate Rule

(CAIR) Technical Support Document (which can be found at

http://www.epa.gov/cair/pdfs/finaltech01.pdf). Using these data, combined growth and

control factors for the period 2002-2009 a nd 2002-2018 were estimated using straight

line interpolation betwee n 1996 and 2010 (for 2009) and 2015 and 2020 (for 2018). This

is done at the State-county-S CC-pollutant level of detail.

(c) The EPA growth and control data are matc hed against the 2002 VISTAS base year data

using State-county-SCC-pollutant as the match key. Ideally, there would be a one-to-one

match and the process would end at this poin t. Unfortunately, actual match results were

not always ideal, so additional matching criteri a were required. For s ubsequent reference,

this initial (highest resolution) matching cr iterion is denoted as the “CAIR-Primary”

criterion.

(d) A second matching criterion is applied that utilizes a simila r, but higher-level SCC (lower

resolution) matching approach. For exam ple, SCC 2275020000 (commercial aircraft) in

the 2002 base year inventory data would be matched with SCC 2275000000 (all aircraft)

in the CAIR data. This criteri on is applied to records in the 2002 base year emissions file

that are not matched using the “CAIR-Primary” criterion, and is also performed at the

State-county-SCC-pollutant level of detail. For subsequent reference, this is denoted as

the “CAIR-Secondary” criterion. At the end of this process, a number of unmatched

records remained, so a third leve l matching criterion was required.

(e) In the third matching step, the most frequent ly used SCC in the EPA CAIR files for each

of the aircraft, locomotive, and commercial ma rine sectors was averaged at the State level

to produce a “default” State and pollutant-sp ecific growth and c ontrol factor for the

sector. The resulting factor is used as a “default” grow th factor for all unmatched

county-SCC-pollutant level data in each State. In effect, St ate-specific growth data are

applied to county level data for which an explicit match between the VISTAS 2002 base

year data and EPA CAIR data could not be developed. The default growth and control

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# SCCs are 2275020000 (commercial aircraft ) for the aircraft sector, 2280002000

(commercial marine diesel total) for the CMV sector, and 2285002000 (railroad

equipment diesel total) for the locomotive s ector. Matches made usi ng this criterion are

denoted as “CAIR-Tertiary” matches.

(f) According to EPA documentation, the CAIR baseline emissions include the impacts of

the (then proposed) Tier 4 (T4) non-road diesel rulemaking, which implements a low

sulfur fuel requirement that affects bo th future CMV and locomotive emissions.

However, the impacts of this rule were origin ally intended to be excluded from the initial

VISTAS 2018 forecast, which was to include on ly “on-the-books” controls. (The T4 rule

was finalized subsequent to the developmen t of the preliminary 2018 inventory in March

of 2004.) Given its final status , T4 impacts were moved into the “on the books” inventory

for non-road equipment. In addition, since th ere are no other proposed rules affecting the

non-road sector between 2002 and 2018, there is no difference between the 2018 “on the

books” and 2018 “on the way” inventories for th e sector; so that only a single forecast

inventory (for each evaluation year) was de veloped. Nevertheless, since the algorithms

developed to produce the VISTAS forecasts we re developed when there was a distinction

between the “on the books” and “on the way” inve ntories, the distinct algorithms used to

produce the two inventories have been ma intained even though the conceptual

distinctions have been lost. This approach was taken for two reasons . First, it allowed the

previously developed algorithms to be uti lized without change. Second, it allowed for

separate treatment of the T4 emissions impact which was important as those impacts

changed between the proposed and final T4 ru les. Thus, previous EPA inventories that

include the proposed T4 impacts would not be accurate. Therefore, the procedural

discussion continues to reflect the distinc tions between non-T4 and T4 emissions, as

these distinctions continue to be intrinsi cally important to the forecasting process.

Therefore, a second set of EPA CAIR files th at excluded the Tier 4 diesel impacts was

obtained and the same matching exercise de scribed above in step s (b) through (e) was

performed using these “No T4” files. It is im portant to note that the matching exercise

described in steps (b) through (e) cannot si mply be replaced because the “No T4” files

obtained from the EPA include only those SCCs specifically a ffected by the T4 rule (i.e.,

diesel CMV and locomotives). So in effect, the matching exercise was augmented (rather

than replaced) with an additio nal three criteria analogous to those described in steps (c)

through (e), and these are denot ed as the “No T4-Primary,” “No T4-Secondary,” and “No

T4-Tertiary” criteria. Because they exclude the impacts of the proposed T4 rule, matches

using the “No T4” criteria supersede matche s made using the basi c CAIR criteria (as

described in steps (c) through (e) above).

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# (g) The CAIR matching criteria were overridden for any record for which States provided

local growth data. Only North Carolina pr ovided these forecasts, as that State has

provided specific growth factors for airport emissions in four counties. Because the

provided data were based on forecasted changes in landings and takeoffs at major North

Carolina airports, the factor s were applied only to commercial (SCC 2275020000) and air

taxi (SCC 2275060000) emissions. Emissions for ecasts for military and general aviation

aircraft operations, as well as all aircraft operations in counties other than the four

identified in the North Carolina growth fact or submission, continued to utilize the growth

factors developed according to steps (b) through (f) above. Table 2.3-7 presents the

locally generated growth factor s applied in North Carolina.

Table 2.3-7 Locally Generated Growth Factors for North Carolina

FIP 2009 Factor 2018 Factor

37067 0.71 0.84

37081 0.97 0.89

37119 1.15 1.01

37183 0.88 0.81

Note:

Growth factor = Year Emissions/2002 Emissions.

Under CAIR approach, 2009 = 1.16 to 1.17 for all 4 counties.

Under CAIR approach, 2018 = 1.36 to 1.37 for all 4 counties.



# (h) Using this approach, each State-county-S CC-pollutant was assigned a combined growth

and control factor using the EPA CAIR for ecast or locally provided data. The 22,838 data

records for aircraft, locomotives, and CMV in the 2002 revised base year emissions file

were assigned growth factors in acco rdance with the following breakdown:

48 records matched State-provided growth factors,

4,179 records matched using the CAIR-Primary criterion,

240 records matched using the CAIR-Secondary criterion,

7,463 records matched using the CAIR-Tertiary criterion,

720 records matched using the No T4-Primary criterion,

3,858 records matched using the No T4-Secondary criterion, and

6,330 records matched using th e No T4-Tertiary criterion.

(i) Finally, the impacts of the T4 rule as adopted were applied to the grown “non T4”

emission estimates. The actual T4 emission st andards do not affect aircraft, locomotive,

or CMV directly, but associated diesel fuel sulfur requirements do affect locomotives and

CMV. Lower fuel sulfur content affects both SO 2 

# and PM emissions. Expected fuel sulfur

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# contents were obtained for each evaluati on year from the EPA technical support

document for the final T4 rule ( Final Regulatory Analysis: C ontrol of Emissions from

Non-road Diesel Engines , EPA420-R-04-007, May 2004). According to that document,

the average diesel fuel sulfur content for locomotives and CMV is expected to be 408

ppmW in 2009 and 56 ppmW in 2018. These co mpare to expected non-T4 fuel sulfur

levels of 2599 ppmW in 2009 and 2336 ppmW in 2018. Table 2.3-8 uses calculated

emissions estimates for base and T4 c ontrol scenarios to estimate emission

reduction impacts.

Table 2.3-8 Estimated Emission Reduc tion Impacts based on T-4 Rule

2009 2018

CMV SO 2 

# = Non-T4 SO 2 

# × 0.1569 0.0241

Locomotive SO 2 

# = Non-T4 SO 2 

# × 0.1569 0.0241

CMV PM = Non-T4 PM × 0.8962 0.8762

Locomotive PM = Non-T4 PM × 0.8117 0.7734



# However, since the diesel fuel sulfur c ontent assumed for the 2002 VISTAS base year

inventory, upon which both the 2009 and 2018 inventories were ba sed, is 2500 ppmW, a

small adjustment to the emission reduction mu ltipliers calculated from the T4 rule is

appropriate since they are measured relative to modestly different sulfur contents (2599

ppmW for 2009 and 2336 ppmW for 2018). Correcting for these modest differences

produces the emission reduction impact estim ates relative to forecasts based on the

VISTAS 2002 inventory shown in Table 2.3-9.

Table 2.3-9 Estimated Emission Reduction Impacts Relative to VISTAS 2002 Base

Year Values

2009 2018

CMV SO 2 

# = Non-T4 SO 2 

# × 0.1632 0.0225

Locomotive SO 2 

# = Non-T4 SO 2 

# × 0.1632 0.0225

CMV PM = Non-T4 PM × 0.9004 0.8685

Locomotive PM = Non-T4 PM × 0.8187 0.7610



# These factors were applied directly to the non-T4 emission forecasts to produce the final

VISTAS 2009 and 2018 emissions inventories for aircraft, locomotive, and CMV.

The only exception is for Palm Beach C ounty, Florida, where CMV emissions are

reported as “all fuels” rather than separately by residual and diesel fuel components. To

estimate T4 impacts in Palm Beach County, th e ratio of diesel CMV emissions to total

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# CMV emissions in the remainder of Florida was calculated and the T4 impact estimates

for Palm Beach County were adjusted to reflect that ratio. Table 2.3-10 shows the

calculated diesel CMV ratios.

Table 2.3-10 Diesel CMV Adjustment Ra tios for Palm Beach County, FL

GROWTH BASIS SO 2 

# PM

2009 (1996, 2020 Growth Basis) 0.2410 0.7861

2009 (1996, 2010, 2015, and 2020 Growth Basis) 0.1279 0.7875

2018 (1996, 2020 Growth Basis) 0.2432 0.7925

2018 (1996, 2010, 2015, and 2020 Growth Basis) 0.2624 0.7918

The differences between the growth bases are discussed in detail below.



# Combining these ratios with the T4 impact es timates for diesel engines, as presented

above, yields the following impact adju stment factors for Palm Beach County:

Table 2.3-11 Overall Adjustment Fact ors for Palm Beach County, FL

GROWTH BASIS

2009 SO 2 

# (19, 20 Growth Basis) 0.7894 [0.1632×0.2410+(1-0.2410)]

2009 SO 2 

# (96, 10, 15, and 20 Growth Basis) 0.8930 [0.1632×0.1279+(1-0.1279)]

2018 SO 2 

# (96, 20 Growth Basis) 0.7623 [0.0225×0.2432+(1-0.2432)]

2018 SO 2 

# (96, 10, 15, and 20 Growth Basis) 0.7436 [0.0225×0.2624+(1-0.2624)]

2009 PM (19, 20 Growth Basis) 0.9217 [0.9004×0.7861+(1-0.7861)]

2009 PM (96, 10, 15, and 20 Growth Basis) 0.9216 [0.9004×0.7875+(1-0.7875)]

2018 PM (96, 20 Growth Basis) 0.8958 [0.8685×0.7925+(1-0.7925)]

2018 PM (96, 10, 15, and 20 Growth Basis) 0.8959 [0.8685×0.7918+(1-0.7918)]

The differences between the growth bases are discussed in detail below.



# Utilizing this approach, emission inventory fo recasts for both 2009 and 2018 were developed. As

indicated in step (b) above, basic growth factor s were developed using EP A CAIR inventory data

for 1996, 2010, 2015, and 2020. From these data, equiva lent EPA CAIR inventories for 2002 and

2009 were developed through linear interpolati on of the 1996 and 2010 inventories, while an

equivalent CAIR inventory for 2018 was develope d through linear interp olation of the 2015 and

2020 inventories. Growth factors for 2009 and 2018 we re then estimated as the ratios of the

CAIR 2009 and 2018 inventories to the CAIR 2002 inventory.

During the development of the preliminary 2018 VI STAS inventory in Ma rch 2004, this process

yielded reasonable results and exhibited no partic ular systematic concerns. However, when the

2009 Base F inventory was developed, significant concerns related to SO 2 

# and PM were

encountered. Essentially, what was revealed by th e Base F 2009 forecast was a series of apparent

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# inconsistencies in the CAIR 2010 and 2015 emissi on inventories (as compared to the 1996 and

2020 CAIR inventories) that were masked during the construction of the “longer-term”

2018 inventory.

The apparent inconsistencies are best illustrated by looking at the actual da ta extracted from the

CAIR inventory files. Note th at although a limited example is be ing presented, the same general

issue applies throughout the CAIR files. Fo r FIP 01001 (Autauga County, Alabama) and SCC

2285002000 (Diesel Rail), the CAIR inventories indicate SO 2 

# emission estimates as shown in

Table 2.3-12.

Table 2.3-12 SO 2 

# Emissions for Diesel Rail in Autauga County, AL from the

CAIR Projections

YEAR TONS

1996: 15.3445

2010: 2.7271

2015: 2.8178

2020: 16.6232



# Clearly, there is a major drop in emissions between 1996 and 2010, followed by a major increase

in emissions between 2015 and 2020. Several ob servations regarding these changes are

important. First, the CAIR data were reported to exclude the T4 rule, so that the drop in

emissions should be related to something other than simply a change in diesel fuel sulfur content.

Second, if the T4 rule impacts we re “accidentally” included in th e estimates, there should be a

resultant 90 percent drop in di esel sulfur between 2010 and 2015; so such inclusion is unlikely.

Third, the rate of growth be tween 2015 and 2020 (43 percent per year compound or 97 percent

per year linear) is well beyond any reasonable expecta tions for rail service; and fuel sulfur

content during this period is constant both with a nd without T4. In short, there appeared to be no

rational explanation for the data, yet the same ba sic relations are observed for thousands of CAIR

inventory records.

For the most part, the issue seems to be centered on SO 2 

# and PM records, which are those

records primarily affected by the T4 rule. But, as noted above, there does not seem to be any

pattern of consistency that would indicate that eith er inclusion or exclusion of T4 rule impacts is

the underlying cause. Moreover, where they occu r, the observed growth extremes generally

affect both SO 2 

# and PM equally, while one would expect PM effects to be buffered if the T4 rule

was the underlying cause, since changes in diesel fu el sulfur content will only affect a fraction of

PM (i.e., sulfate), while directly reducing SO 2



# .

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

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# 169 

# The data presented in Figure 2.3-1 illustrates what this meant to the VISTAS forecasting process.

Figure 2.3-1 depicts the same data presente d above for Autauga County, Alabama, but

normalized so that the interpolated 2002 CAIR em issions estimate equals unity. The “raw” CAIR

data is depicted by the markers labeled A, B, C, and D. Interpolated data for 2002 and 2009,

based on 1996 and 2010 CAIR data, is depicted by the markers labeled “i” and “ii.” Interpolated

data for 2018, based on 2015 and 2020 CAIR data is depicted by the marker labeled “iii.” The

relationship between marker “iii” and marker “i” is exactly the relationship used to construct the

preliminary (e.g., pre-Base F) 2018 VISTAS invent ory (i.e., a linear growth rate equal to 0.7

percent per year). Thus, it is eas y to see that although there is a major “dip and rise” between

2002 and 2018, it is essentially masked unless data for intervening years are examined. Since no

intervening year was examined for the preliminary 2018 inventor y, the “dip and rise” was not

discovered. However, upon the development of the 2009 inventory forecast, the issue became

obvious, as the marker labeled “ii” readily illustrates. In effect, the 2009 inventory reflected very

low negative “growth rates” for some SCCs and pollutants relative to the 2002 inventory, while

the 2018 inventory reflected very high and posi tive growth rates for those same SCCs and

pollutants. In effect, the path between 2002 and 2018 that previously looked like the dotted line

connecting markers “i” and “iii,” now looks like the solid line c onnecting markers “i”, “ii,” and

“iii.” For reference purposes, this path is hereafter referred to as the 1996, 2010, 2015, and 2020

growth basis, since all interpolated data is based on CAIR data for those four years.

Figure 2.3-1 Impacts of the Apparent CAIR Inventory Discrepancy

0.0 0.2 0.4 0.6 0.8 1.0 1.2 1.4 1.6 1.8

1990 1995 2000 2005 2010 2015 2020 2025



# YearEmissions 

# 1

iii

ii i D

C B A 3 2

A,B,C,D = EPA CAIR Data.

i,ii,iii = 96-10-15-20 Interpolations.

1,2,3 = 96-20 Interpolations.

All indicated growth is linear. i to ii = -9.1%/yr ii to iii = 22.9%/yr i to iii = 0.7%/yr 1 to 2 to 3 = 0.3%/yr

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

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# 170 

# In light of the apparent discrepancies i nherent in the 1996, 2010, 2015, and 2020 growth basis

data and the inconsistencies its use would impa rt into the 2009 and 2018 VISTAS inventories, a

secondary forecasting method was developed. This second method relies on the apparent

consistency between the 1996 and 2020 non-T4 CAIR inventories, interpol ating equivalent 2002,

2009, and 2018 inventories solely from these two invent ories. In effect, the CAIR inventories for

2010 and 2015 are ignored. In Figure 2.3-1, this sec ondary approach is depicted by the data

points that lie along the lines connecting markers A and D. Markers A and D represent the 1996

and 2020 CAIR inventories, and the markers labe led 1, 2, and 3 represen t the interpolated 2002,

2009, and 2018 CAIR equivalent inventories. The growth rate between 2009 and 2002 is then

equal to the ratio of the 2009 and 2002 CAIR i nventories, while that between 2018 and 2002 is

equal to the ratio of the 2018 and 2002 CAIR inve ntories. For the exampl e data, the resulting

linear growth estimate is 0.3 per cent per year. For reference pur poses, this path is hereafter

referred to as the 1996-2020 growth basis, since a ll interpolated data are based on CAIR data for

only those two years.

It is perhaps worth noting that the only elemen ts of Figure 2.3-1 that have any bearing on the

VISTAS inventories are the growth rates. The ab solute CAIR data are of importance only in

determining those rates, as all VISTAS inventor ies were developed on the basis of the VISTAS

2002 base year inventory, not any of the CAIR i nventories. So referring to Figure 2.3-1, the two

growth options are summarized in Table 2.3-13.

Table 2.3-13 Growth Options based on CAIR Data

GROWTH BASIS PERCENT PER YEAR

1996, 2010, 2015, 2020 Growth Basis: -9.1% per year (linear) between 2002 and 2009

1996-2020 Growth Basis: +0.3% per year (linear) between 2002 and 2009

1996, 2010, 2015, 2020 Growth Basis: +22.9% per year (linear) between 2009 and 2018

1996-2020 Growth Basis: +0.3% per year (linear) between 2009 and 2018

1996, 2010, 2015, 2020 Growth Basis: +0.7% per year (linear) between 2002 and 2018

1996-2020 Growth Basis: +0.3% per year (linear) between 2002 and 2018



# Of course, these specific rates are applicable only to the example case (i.e., diesel rail SO 2 

# in

Autauga County, Alabama), but there are thousands of additional CAIR reco rds that are virtually

identical from a growth viewpoint.

While forecast inventories for aircraft, lo comotives, and CMV were developed for 2009 and

2018 using both growth methods, it was ultimately decided to utilize the 1996-2020 growth basis

for Base F since it provided more reasonable growth rates for 2009. Tables 2.3-14 and 2.3-15

present a summary of each Base F inventor y, while Tables 2.3-16 and 2.3-17 present the

associated change in emissions for each Base F forecast inventory relative to the Base F 2002

base year VISTAS inventory. Th e larger reduction in CMV SO 2 

# emissions in 2009 and 2018

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

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# 171 

# (relative to 2002) for Virginia and West Virginia is notable relative to the other VISTAS States,

but this has been checked and is attributable to a high diesel cont ribution to total CMV SO 2 

# in

the 2002 inventories for these two States.

Figures 2.3-2 through 2.3-13 graphi cally depict the relationships between the various Base F

inventories and preliminary 2002 an d 2018 projections prepared prio r to Base F. There are two

figures for each pollutant, the first of which presents a comparison of total VISTAS regional

emission estimates for aircraft, locomotives, and CMV, and the second of which presents total

VISTAS region emission estimates for locomotives only. This two figure approach is intended to

provide a more robust illustration of the differences between the various inventories, as some of

the differences are less distinct when viewed th rough overall aggregate em issions totals. All of

the figures include the following emissions estimates:

 

# The 2002 Base F base year VISTAS emissi ons inventory (labeled as “2002”),

 

# The 2002 pre-Base F base year VISTAS emissions inventory (labeled as “2002

Prelim”),

 

# The Base F 2009 VISTAS emissions inventor y developed using gr owth rates derived

from 1996 and 2020 EPA CAIR data (labeled as “2009”),

 

# The Base F 2018 VISTAS emissions inventor y developed using gr owth rates derived

from 1996 and 2020 EPA CAIR data (labeled as “2018”), and

 

# The pre-Base F 2018 VISTAS emissions i nventory estimates as developed using

growth rates derived from 1996, 2010, 2015, and 2020 EPA CAIR data (labeled as

“2018 Prelim”).

All 12 figures generally illustrate a reduction in emissions estimates between the 2002 pre-Base

F emission estimates published in February 2004 (t he initial 2002 VISTAS inventory) and the

2002 Base F emission estimates. This reduction gene rally results from emission updates reflected

in the State 2002 CERR submittals used to de velop the Base F 2002 base year inventory,

although the major differences in ag gregate PM emission estimates are driven to a greater extent

by modifications in the methodology used to estima te aircraft PM in the Base F 2002 base year

inventory (as documented under the base ye ar inventory section of this report).

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# 172 

# Table 2.3-14 Base F 2009 Aircraft, Locomotive, and Non-Recreational Marine Emissions

(annual tons) -- Based on Growth Using 1996 and 2020 EPA Inventories

Source State CO NO

x 

# PM 10 

# PM 2.5 

# SO 2 

# VOC

AL 4,178 202 278 102 19 217

FL 29,258 10,316 2,812 2,756 928 4,235

GA 7,635 6,233 1,712 1,678 523 512

KY 3,075 762 207 203 73 304

MS 1,765 162 51 50 16 108

NC 6,551 1,601 436 427 153 644

SC 7,372 559 446 437 98 975

TN 8,020 3,096 824 807 268 1,050

VA 10,994 3,094 1,239 1,214 907 2,892

WV 1,312 91 28 28 9 74 Aircraft

(2275)

Total 80,159 26,116 8,033 7,704 2,993 11,011

AL 1,280 8,888 872 802 2,753 768

FL 6,236 43,198 1,838 1,691 5,864 1,467

GA 1,097 7,599 317 291 974 256

KY 7,087 48,039 2,158 1,985 8,350 1,649

MS 6,074 41,437 1,821 1,676 6,587 1,415

NC 634 4,386 184 169 584 148

SC 1,133 7,796 326 300 1,012 264

TN 3,887 26,333 1,168 1,074 4,512 904

VA 1,042 2,662 312 286 61 506

WV 1,638 11,073 455 419 89 381 Commercial

Marine

(2280)

Total 30,109 201,412 9,450 8,693 30,786 7,759

VA 118 299 23 21 5 50 Military Marine

(2283) Total 118 299 23 21 5 50

AL 3,648 23,529 452 406 242 1,279

FL 1,052 8,905 189 170 101 382

GA 2,769 24,398 507 456 271 1,003

KY 2,264 19,597 415 374 221 819

MS 2,406 20,785 441 397 239 849

NC 1,712 14,741 313 282 167 618

SC 1,213 10,443 222 200 119 437

TN 2,745 23,924 483 435 240 984

VA 1,236 11,134 1,167 1,050 608 467

WV 1,369 12,177 251 226 135 489 Locomotives

(2285)

Total 20,412 169,635 4,440 3,995 2,343 7,328

Grand Total 130,798 397,462 21,946 20,413 36,126 26,148

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# 173 

# Table 2.3-15 Base F 2018 Aircraft, Locomotive, and Non-Recreational Marine Emissions

(annual tons) -- Based on Growth Using 1996 and 2020 EPA Inventories

Source State CO NO

x 

# PM 10 

# PM 2.5 

# SO 2 

# VOC

AL 4,681 236 345 122 23 245

FL 34,178 12,147 3,312 3,246 1,093 4,976

GA 8,939 7,340 2,016 1,976 616 601

KY 3,602 898 244 239 86 357

MS 1,986 190 60 58 18 122

NC 6,728 1,454 400 392 139 615

SC 8,487 616 493 484 112 1,119

TN 9,009 3,519 939 921 309 1,187

VA 12,578 3,528 1,370 1,342 1,063 3,358

WV 1,484 106 33 33 10 85 Aircraft

(2275)

Total 91,670 30,035 9,213 8,814 3,468 12,666

AL 1,388 8,464 880 809 2,715 809

FL 6,684 41,117 1,853 1,705 6,248 1,543

GA 1,174 7,246 319 293 976 269

KY 7,703 45,174 2,199 2,023 8,383 1,752

MS 6,571 39,129 1,850 1,702 6,556 1,498

NC 679 4,179 185 170 596 155

SC 1,217 7,406 329 303 1,027 278

TN 4,225 24,763 1,190 1,095 4,808 960

VA 1,133 2,517 314 289 9 537

WV 1,781 10,412 459 422 13 404 Commercial

Marine

(2280)

Total 32,554 190,407 9,578 8,811 31,330 8,205

VA 128 282 23 21 1 53 Military Marine

(2283) Total 128 282 23 21 1 53

AL 3,850 19,917 381 343 34 1,183

FL 1,110 7,538 159 143 14 353

GA 2,917 21,395 427 385 38 932

KY 2,389 16,751 352 317 31 757

MS 2,540 17,594 372 335 34 785

NC 1,807 12,478 264 237 24 571

SC 1,280 8,840 187 168 17 404

TN 2,897 21,735 407 367 34 910

VA 1,300 10,173 983 885 86 436

WV 1,444 10,831 212 190 19 453 Locomotives

(2285)

Total 21,534 147,252 3,744 3,368 333 6,785

Grand Total 145,885 367,975 22,557 21,015 35,132 27,709

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# 174 

# Table 2.3-16 Change in Emissions between 20 09 and 2002 Base F Inventories (Based on

Growth Using 1996 and 2020 EPA Inventories)

Source State CO NO

x 

# PM 10 

# PM 2.5 

# SO 2 

# VOC

AL +10% +15% +23% +18% +16% +11%

FL +15% +16% +16% +16% +16% +16%

GA +15% +16% +16% +16% +16% +16%

KY +15% +16% +16% +16% +16% +16%

MS +11% +16% +15% +15% +16% +12%

NC +8% +3% +4% +4% +3% +5%

SC +13% +9% +9% +9% +12% +13%

TN +11% +12% +12% +12% +14% +11%

VA +13% +12% +9% +9% +15% +14%

WV +11% +16% +15% +15% +16% +12% Aircraft

(2275)

Total +13% +14% +14% +13% +15% +14%

AL +7% -4% -5% -5% -18% +4%

FL +6% -4% -5% -5% -12% +4%

GA +6% -3% -5% -5% -17% +4%

KY +7% -4% -4% -4% -13% +5%

MS +7% -4% -4% -4% -15% +5%

NC +6% -4% -5% -5% -15% +4%

SC +6% -4% -5% -5% -16% +4%

TN +7% -4% -4% -4% -9% +5%

VA +7% -4% -7% -7% -83% +5%

WV +7% -4% -7% -7% -83% +5% Commercial

Marine

(2280)

Total +7% -4% -5% -5% -15% +5%

VA +7% -4% -7% -7% -83% +5% Military Marine

(2283) Total +7% -4% -7% -7% -83% +5%

AL +5% -11% -24% -24% -83% -6%

FL +5% -11% -24% -24% -83% -6%

GA +4% -9% -24% -24% -83% -5%

KY +5% -10% -23% -23% -83% -6%

MS +5% -11% -24% -24% -83% -6%

NC +5% -11% -24% -24% -83% -6%

SC +5% -11% -24% -24% -83% -6%

TN +5% -7% -24% -24% -83% -6%

VA +4% -6% -24% -24% -83% -5%

WV +4% -8% -24% -24% -83% -5% Locomotives

(2285)

Total +4% -9% -24% -24% -83% -5%

Grand Total +10% -5% -4% -4% -32% +5%

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# Table 2.3-17 Change in Emissions between 20 18 and 2002 Base F Inventories (Based on

Growth Using 1996 and 2020 EPA Inventories)

Source State CO NO

x 

# PM 10 

# PM 2.5 

# SO 2 

# VOC

AL +24% +35% +53% +41% +36% +25%

FL +34% +37% +37% +37% +37% +36%

GA +35% +37% +37% +37% +37% +36%

KY +35% +37% +37% +37% +37% +36%

MS +25% +36% +35% +35% +36% +27%

NC +10% -6% -5% -5% -6% 0%

SC +30% +20% +21% +21% +27% +30%

TN +24% +27% +28% +28% +31% +26%

VA +29% +28% +20% +20% +35% +33%

WV +26% +36% +35% +35% +36% +28% Aircraft

(2275)

Total +29% +31% +30% +30% +33% +31%

AL +16% -8% -4% -4% -19% +10%

FL +14% -8% -4% -4% -7% +9%

GA +13% -8% -5% -5% -17% +9%

KY +17% -10% -2% -2% -13% +12%

MS +16% -9% -3% -3% -15% +11%

NC +13% -8% -4% -4% -14% +9%

SC +14% -9% -4% -4% -15% +10%

TN +17% -10% -2% -2% -3% +12%

VA +17% -9% -6% -6% -98% +11%

WV +17% -10% -6% -6% -98% +12% Commercial

Marine

(2280)

Total +15% -9% -3% -3% -14% +11%

VA +17% -10% -6% -6% -98% +12% Military Marine

(2283) Total +17% -10% -6% -6% -98% +12%

AL +10% -24% -36% -36% -98% -13%

FL +10% -24% -36% -36% -98% -13%

GA +10% -20% -36% -36% -98% -12%

KY +10% -23% -35% -35% -98% -13%

MS +10% -24% -36% -36% -98% -13%

NC +10% -24% -36% -36% -98% -13%

SC +10% -24% -36% -36% -98% -13%

TN +10% -15% -36% -36% -98% -13%

VA +10% -14% -36% -36% -98% -11%

WV +10% -18% -36% -36% -98% -12% Locomotives

(2285)

Total +10% -21% -36% -36% -98% -12%

Grand Total +23% -12% -1% -1% -34% +11%

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# 176 118,739 130,798 145,885

129,659 159,122

0 20,000 40,000 60,000 80,000 100,000 120,000 140,000 160,000 180,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

n

s

p

e

r

Y

e

a

r

19,540 20,412 21,534 21,980 23,849

0 5,000 10,000 15,000 20,000 25,000 30,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

n

s

p

e

r

Y

e

a

r 

# Figure 2.3-2 Total Aircraft, Locomoti ve, and CMV CO Emissions (Base F)

Figure 2.3-3 Locomotive CO Emissions (Base F)

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# 177 420,228

397,462

367,975 455,067

395,049

0 50,000 100,000 150,000 200,000 250,000 300,000 350,000 400,000 450,000 500,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

n

s

p

e

r

Y

e

a

r

187,044

169,635

147,252 211,588

167,783

0 50,000 100,000 150,000 200,000 250,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

n

s

p

e

r

Y

e

a

r 

# Figure 2.3-4 Total Aircraft, Locomotive, and CMV NO

x 

# Emissions (Base F)

Figure 2.3-5 Locomotive NO

x 

# Emissions (Base F)

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# 178 22,823 21,946 22,557 100,452 128,715

0 20,000 40,000 60,000 80,000 100,000 120,000 140,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

n

s

p

e

r

Y

e

a

r

5,815

4,440

3,744 6,118

3,947

0 1,000 2,000 3,000 4,000 5,000 6,000 7,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

n

s

p

e

r

Y

e

a

r 

# Figure 2.3-6 Total Aircraft, Locomotive, and CMV PM 10 

# Emissions (Base F)

Figure 2.3-7 Locomotive PM 10 

# Emissions (Base F)

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# 179 5,232

3,995

3,368 5,505

3,552

0 1,000 2,000 3,000 4,000 5,000 6,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

n

s

p

e

r

Y

e

a

r 21,170 20,413 21,015 73,099 92,207

0 10,000 20,000 30,000 40,000 50,000 60,000 70,000 80,000 90,000 100,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

n

s

p

e

r

Y

e

a

r 

# Figure 2.3-8 Total Aircraft, Locomotive, and CMV PM 2.5 

# Emissions (Base F)

Figure 2.3-9 Locomotive PM 2.5 

# Emissions (Base F)

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

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# 180 14,022

2,343

333 14,947

1,553

0 2,000 4,000 6,000 8,000 10,000 12,000 14,000 16,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

n

s

p

e

r

Y

e

a

r 52,931

36,126 35,132 57,062

41,284

0 10,000 20,000 30,000 40,000 50,000 60,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

n

s

p

e

r

Y

e

a

r 

# Figure 2.3-10 Total Aircraft, Locomotive, and CMV SO 2 

# Emissions (Base F)

Figure 2.3-11 Locomotive SO 2 

# Emissions (Base F)

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# 181 7,750

7,328

6,785 8,738

7,544

0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

n

s

p

e

r

Y

e

a

r 24,881 26,148 27,709

26,877 29,228

22,000 23,000 24,000 25,000 26,000 27,000 28,000 29,000 30,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

n

s

p

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Y

e

a

r 

# Figure 2.3-12 Total Aircraft, Locomotive , and CMV VOC Emissions (Base F)

Figure 2.3-13 Locomotive VOC Emissions (Base F)

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# 182 

# Base G Revisions:

Table 2.3-18 shows the Base G 2002 base year em issions for each State in the VISTAS region

for aircraft, locomotives and CMV. Although some of these data are updated relative to those

used as the basis of the Base F emissions fo recasts, the methodology used to develop 2009 and

2018 emissions forecasts for aircraft, locomotives, and CMV for Base G is identical to that used

for Base F (as documented above). The only exceptions are as follows:

(a) As indicated in the discussion of the Base F forecasts, the CAIR (growth rate) matching

criteria were overridden for any record for which States provided local growth data. For

Base F, only North Carolina provided su ch data. However, for Base G, Kentucky

regulators provided growth data for aircraft emissions associated with

Cincinnati/Northern Kentucky Internati onal Airport (located in Boone County,

Kentucky). These data were applied to all po llutants and all aircraft types (i.e., military

aircraft (SCC 2275001000), commercial ai rcraft (SCC 2275020000), general aviation

aircraft (SCC 2275050000), and air taxi airc raft (SCC 2275060000)). Emissions forecasts

for all aircraft operations in counties other than Boone con tinued to utilize the growth

factors developed according to the CAIR ma tching criteria. Table 2.3-19 presents the

locally generated growth fact ors applied in Kentucky. It should be recognized that

although the locally provided gr owth factors presented in the table are significantly

greater than those that would apply under the CAIR matching criteria, this is to be

expected as local regulators noted a very significant decline in activity at the

Cincinnati/Northern Kentucky International Airport in 2002 (relati ve to activity in

preceding years). Moreover, this downward spike seems to have been alleviated since

2002, so that the provided growth factors repr esent not only “routine” growth expected

between 2002 and the two forecast years, but growth required to offset the temporary

decline observed in 2002.

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

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# 183 

# Table 2.3-18 Base G 2002 Aircraft, Locomotive, and Non-Recreational Marine Emissions

(annual tons)

Source State CO NO

x 

# PM 10 

# PM 2.5 

# SO 2 

# VOC

AL 5,595 185 238 99 18 276

FL 25,431 8,891 2,424 2,375 800 3,658

GA 6,620 5,372 1,475 1,446 451 443

KY 5,577 925 251 246 88 397

MS 1,593 140 44 43 13 96

NC 6,088 1,548 419 411 148 613

SC 6,505 515 409 401 88 863

TN 7,251 2,766 734 719 235 943

VA 11,873 3,885 2,010 1,970 272 2,825

WV 1,178 78 25 24 8 66 Aircraft

(2275)

Total 77,712 24,305 8,029 7,734 2,121 10,179

AL 1,196 9,218 917 844 3,337 737

FL 5,888 44,817 1,936 1,781 6,683 1,409

GA 1,038 7,875 334 307 1,173 246

KY 6,607 50,267 2,246 2,066 9,608 1,569

MS 5,688 43,233 1,903 1,751 7,719 1,351

NC 599 4,547 193 178 690 142

SC 1,067 8,100 343 316 1,205 253

TN 3,624 27,555 1,217 1,120 4,974 860

VA 972 2,775 334 307 359 483

WV 1,528 11,586 487 448 525 362 Commercial

Marine

(2280)

Total 28,207 209,972 9,911 9,118 36,275 7,413

VA 110 313 25 23 27 48 Military Marine

(2283) Total 110 313 25 23 27 48

AL 3,518 26,623 592 533 1,446 1,365

FL 1,006 9,969 247 222 605 404

GA 2,654 26,733 664 598 1,622 1,059

KY 2,166 21,811 542 488 1,321 867

MS 2,302 23,267 578 520 1,429 899

NC 1,638 16,502 410 369 1,001 654

SC 1,160 11,690 291 261 710 462

TN 2,626 25,627 633 570 1,439 1,041

VA 1,186 11,882 1,529 1,375 3,641 492

WV 1,311 13,224 329 296 808 517 Locomotives

(2285)

Total 19,568 187,328 5,815 5,232 14,022 7,761

Grand Total 125,597 421,918 23,780 22,107 52,444 25,401

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

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# 184 

# Table 2.3-19 Locally Generated Growth Factors for Kentucky

FIP 2009 Factor 2018 Factor

21015 1.31 1.81

Note:

Growth factor = Year Emissions/2002 Emissions.

Under CAIR approach, 2009 = 0.99 to 1.17.

Under CAIR approach, 2018 = 0.97 to 1.40.



# (b) Because of the additional emissions records added in Alabama, as discussed in the Base

G 2002 base year inventory section of this re port, the total number of emissions records

in the Base G 2009 and 2018 forecasts incr eased to 23,042 (as compared to 22,838 for

Base F). The 23,042 data records for aircra ft, locomotives, and CMV were assigned

growth factors in accordance with the following breakdown:

72 records matched State-provided growth factors,

4,287 records matched using the CAIR-Primary criterion,

240 records matched using the CAIR-Secondary criterion,

7,511 records matched using the CAIR-Tertiary criterion,

720 records matched using the No T4-Primary criterion,

3,858 records matched using the No T4-Secondary criterion, and

6,354 records matched using th e No T4-Tertiary criterion.

Tables 2.3-20 and 2.3-21 present a summary of the resulting Base G 2009 and 2018 inventories,

while Tables 2.3-22 and 2.3-23 present the associ ated change in emissions for each forecast

inventory relative to the Base G 2002 base year VISTAS. As was th e case with Base F, the larger

reduction in CMV SO 2 

# emissions in 2009 and 2018 (relative to 2002) for Virginia and West

Virginia is notable relative to the other VISTAS States, but is attribut able to a high diesel

contribution to total CMV SO 2 

# in the 2002 inventories for these two States.

Figures 2.3-14 through 2.3-25 graphically depict the relationships between the various

inventories, as revised through Base G. There are two figures for each pollutant, the first of

which presents a comparison of total VISTAS regional emission estimates for aircraft,

locomotives, and CMV, and the second of wh ich presents total VISTAS region emission

estimates for locomotives only. This two figure a pproach is intended to provide a more robust

illustration of the differences between the various inventories, as some of the differences are less

distinct when viewed through overall aggregate em issions totals. All of the figures include the

following emissions estimates:

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

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# 185 

#  

# The Base G 2002 base year VISTAS emissi ons inventory (labeled as “2002”),

 

# The pre-Base F 2002 base year VISTAS emissions inventory (labeled as “2002

Prelim”),

 

# The Base G 2009 VISTAS emissions inventor y developed using gr owth rates derived

from 1996 and 2020 EPA CAIR data (labeled as “2009”),

 

# The Base G 2018 VISTAS emissions inventor y developed using gr owth rates derived

from 1996 and 2020 EPA CAIR data (labeled as “2018”), and

 

# The pre-Base F 2018 VISTAS emissions inve ntory estimates developed using growth

rates derived from 1996, 2010, 2015, and 2020 EPA CAIR data (labeled as “2018

Prelim”).

All 12 figures generally illustrate a reduction in emissions estimates between the pre-Base F

2002 emission estimates published in February 2004 and the Base G 2002 base year emission

estimates. This reduction generally results from emission updates reflected in the Base F State

CERR submittals, although the major differences in aggregate PM emission estimates are driven

to a greater extent by modifications in the me thodology used to estimate aircraft PM in the

Base F revisions to the 2002 Base F base year inventory (as documented under the base year

inventory section of this report).

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

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# 186 

# Table 2.3-20 Base G 2009 Aircraft, Locomotive, and Non-Recreational Marine Emissions

(annual tons) -- Based on Growth Using 1996 and 2020 EPA Inventories

Source State CO NO

x 

# PM 10 

# PM 2.5 

# SO 2 

# VOC

AL 6,265 213 292 116 21 309

FL 29,258 10,316 2,812 2,756 928 4,235

GA 7,635 6,233 1,712 1,678 523 512

KY 6,959 1,135 307 301 108 487

MS 1,765 162 51 50 16 108

NC 6,991 1,795 486 477 171 709

SC 7,372 559 446 437 98 975

TN 8,020 3,096 824 807 268 1,050

VA 13,141 4,244 2,124 2,082 306 3,153

WV 1,312 91 28 28 9 74 Aircraft

(2275)

Total 88,716 27,844 9,083 8,732 2,447 11,612

AL 1,280 8,888 872 802 2,753 768

FL 6,236 43,198 1,838 1,691 5,864 1,467

GA 1,097 7,599 317 291 974 256

KY 7,087 48,039 2,158 1,985 8,350 1,649

MS 6,074 41,437 1,821 1,676 6,587 1,415

NC 634 4,386 184 169 584 148

SC 1,133 7,796 326 300 1,012 264

TN 3,887 26,333 1,168 1,074 4,512 904

VA 1,042 2,662 312 286 61 506

WV 1,638 11,073 455 419 89 381 Commercial

Marine

(2280)

Total 30,108 201,412 9,450 8,693 30,786 7,759

VA 118 299 23 21 5 50 Military Marine

(2283) Total 118 299 23 21 5 50

AL 3,677 23,783 452 406 242 1,289

FL 1,052 8,905 189 170 101 382

GA 2,769 24,398 507 456 271 1,003

KY 2,264 19,597 415 374 221 819

MS 2,406 20,785 441 397 239 849

NC 1,690 14,662 311 279 165 613

SC 1,213 10,443 222 200 119 437

TN 2,745 23,924 483 435 240 984

VA 1,236 11,134 1,167 1,050 608 467

WV 1,369 12,177 251 226 135 489 Locomotives

(2285)

Total 20,420 169,808 4,437 3,993 2,341 7,333

Grand Total 139,362 399,364 22,994 21,440 35,578 26,754

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

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# 187 

# Table 2.3-21 Base G 2018 Aircraft, Locomotive, and Non-Recreational Marine Emissions

(annual tons) -- Based on Growth Using 1996 and 2020 EPA Inventories

Source State CO NO

x 

# PM 10 

# PM 2.5 

# SO 2 

# VOC

AL 7,126 249 361 139 24 352

FL 34,178 12,147 3,312 3,246 1,093 4,976

GA 8,939 7,340 2,016 1,976 616 601

KY 9,078 1,446 391 383 138 623

MS 1,986 190 60 58 18 122

NC 8,150 2,114 572 561 202 831

SC 8,487 616 493 484 112 1,119

TN 9,009 3,519 939 921 309 1,187

VA 14,770 4,706 2,271 2,226 349 3,574

WV 1,484 106 33 33 10 85 Aircraft

(2275)

Total 103,206 32,435 10,450 10,027 2,871 13,472

AL 1,388 8,464 880 809 2,715 809

FL 6,684 41,117 1,853 1,705 6,248 1,543

GA 1,174 7,246 319 293 976 269

KY 7,703 45,174 2,199 2,023 8,383 1,752

MS 6,571 39,129 1,850 1,702 6,556 1,498

NC 678 4,179 185 170 596 155

SC 1,217 7,406 329 303 1,027 278

TN 4,225 24,763 1,190 1,095 4,808 960

VA 1,133 2,517 314 289 9 537

WV 1,781 10,412 459 422 13 404 Commercial

Marine

(2280)

Total 32,554 190,407 9,578 8,811 31,330 8,205

VA 128 282 23 21 1 53 Military Marine

(2283) Total 128 282 23 21 1 53

AL 3,881 20,131 381 343 34 1,192

FL 1,110 7,538 159 143 14 353

GA 2,917 21,395 427 385 38 932

KY 2,389 16,751 352 317 31 757

MS 2,540 17,594 372 335 34 785

NC 1,782 12,539 263 237 23 570

SC 1,280 8,840 187 168 17 404

TN 2,897 21,735 407 367 34 910

VA 1,300 10,173 983 885 86 436

WV 1,444 10,831 212 190 19 453 Locomotives

(2285)

Total 21,539 147,527 3,743 3,368 332 6,792

Grand Total 157,427 370,651 23,794 22,227 34,534 28,522

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

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# 188 

# Table 2.3-22 Change in Emissions between 2009 Base G and 2002 Base F Inventories

(Based on Growth Using 1996 and 2020 EPA Inventories)

Source State CO NO

x 

# PM 10 

# PM 2.5 

# SO 2 

# VOC

AL +12% +15% +23% +18% +16% +12%

FL +15% +16% +16% +16% +16% +16%

GA +15% +16% +16% +16% +16% +16%

KY +25% +23% +23% +23% +23% +23%

MS +11% +16% +15% +15% +16% +12%

NC +15% +16% +16% +16% +16% +16%

SC +13% +9% +9% +9% +12% +13%

TN +11% +12% +12% +12% +14% +11%

VA +11% +9% +6% +6% +12% +12%

WV +11% +16% +15% +15% +16% +12% Aircraft

(2275)

Total +14% +15% +13% +13% +15% +14%

AL +7% -4% -5% -5% -18% +4%

FL +6% -4% -5% -5% -12% +4%

GA +6% -3% -5% -5% -17% +4%

KY +7% -4% -4% -4% -13% +5%

MS +7% -4% -4% -4% -15% +5%

NC +6% -4% -5% -5% -15% +4%

SC +6% -4% -5% -5% -16% +4%

TN +7% -4% -4% -4% -9% +5%

VA +7% -4% -7% -7% -83% +5%

WV +7% -4% -7% -7% -83% +5% Commercial

Marine

(2280)

Total +7% -4% -5% -5% -15% +5%

VA +7% -4% -7% -7% -83% +5% Military Marine

(2283) Total +7% -4% -7% -7% -83% +5%

AL +5% -11% -24% -24% -83% -6%

FL +5% -11% -24% -24% -83% -6%

GA +4% -9% -24% -24% -83% -5%

KY +5% -10% -23% -23% -83% -6%

MS +5% -11% -24% -24% -83% -6%

NC +3% -11% -24% -24% -83% -6%

SC +5% -11% -24% -24% -83% -6%

TN +5% -7% -24% -24% -83% -6%

VA +4% -6% -24% -24% -83% -5%

WV +4% -8% -24% -24% -83% -5% Locomotives

(2285)

Total +4% -9% -24% -24% -83% -6%

Grand Total +11% -5% -3% -3% -32% +5%

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

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# 189 

# Table 2.3-23 Change in Emissions between 2018 Base G and 2002 Base F Inventories

(Based on Growth Using 1996 and 2020 EPA Inventories)

Source State CO NO

x 

# PM 10 

# PM 2.5 

# SO 2 

# VOC

AL +27% +35% +52% +41% +36% +28%

FL +34% +37% +37% +37% +37% +36%

GA +35% +37% +37% +37% +37% +36%

KY +63% +56% +56% +56% +56% +57%

MS +25% +36% +35% +35% +36% +27%

NC +34% +37% +36% +36% +37% +36%

SC +30% +20% +21% +21% +27% +30%

TN +24% +27% +28% +28% +31% +26%

VA +24% +21% +13% +13% +28% +27%

WV +26% +36% +35% +35% +36% +28% Aircraft

(2275)

Total +33% +33% +30% +30% +35% +32%

AL +16% -8% -4% -4% -19% +10%

FL +14% -8% -4% -4% -7% +9%

GA +13% -8% -5% -5% -17% +9%

KY +17% -10% -2% -2% -13% +12%

MS +16% -9% -3% -3% -15% +11%

NC +13% -8% -4% -4% -14% +9%

SC +14% -9% -4% -4% -15% +10%

TN +17% -10% -2% -2% -3% +12%

VA +17% -9% -6% -6% -98% +11%

WV +17% -10% -6% -6% -98% +12% Commercial

Marine

(2280)

Total +15% -9% -3% -3% -14% +11%

VA +17% -10% -6% -6% -98% +12% Military Marine

(2283) Total +17% -10% -6% -6% -98% +12%

AL +10% -24% -36% -36% -98% -13%

FL +10% -24% -36% -36% -98% -13%

GA +10% -20% -36% -36% -98% -12%

KY +10% -23% -35% -35% -98% -13%

MS +10% -24% -36% -36% -98% -13%

NC +9% -24% -36% -36% -98% -13%

SC +10% -24% -36% -36% -98% -13%

TN +10% -15% -36% -36% -98% -13%

VA +10% -14% -36% -36% -98% -11%

WV +10% -18% -36% -36% -98% -12% Locomotives

(2285)

Total +10% -21% -36% -36% -98% -12%

Grand Total +25% -12% +0% +1% -34% +12%

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

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# 190 125,597 139,362 157,427

129,659 159,122

0 20,000 40,000 60,000 80,000 100,000 120,000 140,000 160,000 180,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

n

s

p

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r

Y

e

a

r



# 19,568 20,420 21,539 21,980 23,849

0 5,000 10,000 15,000 20,000 25,000 30,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

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# Figure 2.3-14 Total Aircraft, Locomotive , and CMV CO Emissions (Base G)

Figure 2.3-15 Locomotive CO Emissions (Base G)

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

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# 191 421,918

399,364

370,651 455,067

395,049

0 50,000 100,000 150,000 200,000 250,000 300,000 350,000 400,000 450,000 500,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

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# 187,328

169,808

147,527 211,588

167,783

0 50,000 100,000 150,000 200,000 250,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

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# Figure 2.3-16 Total Aircraft, Locomotive, and CMV NO

x 

# Emissions (Base G)

Figure 2.3-17 Locomotive NO

x 

# Emissions (Base G)

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

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# 192 23,780 22,994 23,794 100,452 128,715

0 20,000 40,000 60,000 80,000 100,000 120,000 140,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

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# 5,815

4,437

3,743 6,118

3,947

0 1,000 2,000 3,000 4,000 5,000 6,000 7,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

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# Figure 2.3-18 Total Aircraft, Locomotive, and CMV PM 10 

# Emissions (Base G)

Figure 2.3-19 Locomotive PM 10 

# Emissions (Base G)

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

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# 193 22,107 21,440 22,227 73,099 92,207

0 10,000 20,000 30,000 40,000 50,000 60,000 70,000 80,000 90,000 100,000

2002 2009 2018 2002 Prelim 2018 Prelim T

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# 5,232

3,993

3,368 5,505

3,552

0 1,000 2,000 3,000 4,000 5,000 6,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

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# Figure 2.3-20 Total Aircraft, Locomotive, and CMV PM 2.5 

# Emissions (Base G)

Figure 2.3-21 Locomotive PM 2.5 

# Emissions (Base G)

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# 194 52,444

35,578 34,534 57,062

41,284

0 10,000 20,000 30,000 40,000 50,000 60,000

2002 2009 2018 2002 Prelim 2018 Prelim T

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# 14,022

2,341

332 14,947

1,553

0 2,000 4,000 6,000 8,000 10,000 12,000 14,000 16,000 18,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

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# Figure 2.3-22 Total Aircraft, Locomotive, and CMV SO 2 

# Emissions (Base G)

Figure 2.3-23 Locomotive SO 2 

# Emissions (Base G)

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# 195 25,401 26,754 28,522

26,877 29,228

0 5,000 10,000 15,000 20,000 25,000 30,000 35,000

2002 2009 2018 2002 Prelim 2018 Prelim T

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# 7,761

7,333

6,792 8,738

7,544

0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 8,000 9,000 10,000

2002 2009 2018 2002 Prelim 2018 Prelim T

o

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# Figure 2.3-24 Total Aircraft, Locomotive , and CMV VOC Emissions (Base G)

Figure 2.3-25 Locomotive VOC Emissions (Base G)

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

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# 196 

# 2.3.4.3 Emissions from NONROAD Model Sources in Illinois, Indiana, and Ohio

Base G projection inventories for 2009 and 2018 for NONROAD model sources in the states of

Illinois, Indiana, and Ohio were produced us ing a methodology identical to that employed to

develop a Base G 2002 base year inventory for th e same states (as documented earlier in this

report). This method consists of the extraction of a complete set of county-level input data

applicable to each of the three st ates (in each of the two projection years) from the latest version

of the EPA’s NMIM model. This includes appr opriate consideration of all non-default NMIM

input files generated by the Midw est Regional Planning Organizati on as documented earlier in

the discussion of the Base G 2002 base year inve ntory. These input data were then assembled

into appropriate input files for the Final NONROAD2005 model and emission estimates were

produced using the same procedure employed for the VISTAS region.

Changes noted between the base year (2002) and forecast year (2009 and 2018) input data

extracted from NMIM include differences in gaso line vapor pressure, gaso line sulfur content,

and diesel sulfur content in most counties. All temperature data (minimum, maximum, and

average daily temperatures) was constant across years.

As described in the discussion of the Base G 2002 base year inventory, counties in the three

states were grouped for modeling purposes using a temperature aggregation scheme that allowed

for county-specific temperature vari ations of no more that 2 oF fr om group average temperatures

(for all temperature inputs). The same grouping scheme was applied to projection year modeling,

so that Illinois emissions were modeled using 12 county groups, Indiana emissions were modeled

using 9 county groups, and Ohio emissions were modeled using 10 county groups. Thus, 31

iterations of NONROAD2002 were re quired per season per projection year, as compared to the

53 iterations per season pe r projection year required for the VISTAS region.

As was also described in th e discussion of the Base G 2002 base year inventory, several

non-default equipment population, growth, activit y, seasonal distribution, and county allocation

files are assigned by NMIM model inputs for these counties. As was the case for the base year

inventory development, these same non-default assignments were retained for both

projection inventories.

2.3.4.4 Differences between 2009/2018

Methodologically, there was no difference in the way that 2009 and 2018 emissions were

calculated for non-road mobile sources. The actual value of the growth fact ors were different for

each type of mobile source considered, but the calculation methods were identical.

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

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# 197 

# 2.3.5 Quality Assurance steps

Throughout the inventory developm ent process, quality assuran ce steps were performed to

ensure that no double counting of emissions o ccurred, to ensure that a full and complete

inventory was developed for VISTAS, and to ma ke sure that projecti on calculations were

working correctly. Quality assurance was an impo rtant component to the inventory development

process and MACTEC performed the following QA steps on mobile source components of the

2009 and revised 2018 projection inventories:

1. All final files (NONROAD only) were run through EPA’s Format and Content

checking software. Input data files for MOBILE and VMT growth estimates were

reviewed by the corresponding SIWG and by the VISTAS Emission Inventory

Technical Advisor.

2. SCC level emission summaries were prepared and evaluated to ensure that emissions

were consistent and that there we re no missing sour ces (NONROAD only).

3. Tier comparisons (by pollutant) were developed between the 2002 base year

inventory and the 2009 and 2018 projecti on inventories (NONR OAD only). Total

VISTAS level summaries by pollutant were developed for these sources to compare

Base F and Base G emission levels.

4. Data product summaries were provided to both the VISTAS Emission Inventory

Technical Advisor and to the SIWG repr esentatives for review and comment.

Changes based on these comments were implemented in the files.

5. Version numbering was used for all i nventory files developed. The version

numbering process used a decimal system to track major and minor changes. For

example, a major change would result in a version going from 1.0 to 2.0. A minor

change would cause a version number to go from 1.0 to 1.1. Minor changes resulting

from largely editorial changes would result in a change from 1.00 to 1.01.

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix A MACTEC, Inc. 

# 198 

# Appendix A:

STATE EMISSION TOTALS BY POLLUTANT AND SECTORDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix AMACTEC, Inc.199Annual CO Emissions by Source Sector01,000,0002,000,0003,000,0004,000,0005,000,0006,000,0007,000,0008,000,000 A L FL GA KY MS N C SC TN V A W V

Tons per yearFIRESAREANONROADONROADNONEGUEGU2002 Actual EGU and Fires2002 Typical EGU and Fires20092018

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix A MACTEC, Inc. 

# 200 

# Annual CO Emissions by Source Sector

Name EGU NONEGU ONROAD NONROAD AREA FIRES YEAR

11,279 174,271 1,321,528 414,385 83,958 474,959 2002 Actual

11,460 174,260 1,321,528 414,385 83,958 514,120 2002 Typical

14,986 180,369 915,647 454,686 66,654 534,873 2009 AL

24,342 201,663 676,210 488,924 59,626 535,658 2018

57,113 81,933 4,550,447 1,920,729 71,079 790,620 2002 Actual

55,899 81,928 4,550,447 1,920,729 71,079 923,310 2002 Typical

71,072 87,661 3,352,509 2,104,920 57,011 923,310 2009 FL

85,495 97,438 2,554,160 2,323,327 53,903 923,310 2018

9,712 130,850 2,735,968 791,158 108,083 654,411 2002 Actual

9,650 130,850 2,735,968 791,158 108,083 620,342 2002 Typical

23,721 147,427 1,983,803 882,970 94,130 637,177 2009 GA

44,269 167,904 1,476,981 973,872 93,827 637,177 2018

12,619 109,936 1,230,148 325,993 66,752 8,703 2002 Actual

12,607 109,936 1,230,148 325,993 66,752 24,900 2002 Typical

15,812 122,024 963,762 357,800 57,887 31,810 2009 KY

17,144 139,437 807,536 381,215 54,865 33,296 2018

5,303 54,568 864,290 236,752 37,905 13,209 2002 Actual

5,219 54,568 864,290 236,752 37,905 14,353 2002 Typical

7,116 57,749 609,972 257,453 27,184 48,160 2009 MS

17,348 65,884 445,493 270,726 22,099 50,037 2018

13,885 50,576 2,873,992 808,231 345,315 34,515 2002 Actual

14,074 50,576 2,873,992 808,231 345,315 71,970 2002 Typical

14,942 53,744 1,991,708 887,605 301,163 96,258 2009 NC

19,870 62,197 1,362,214 960,709 290,809 111,266 2018

6,990 56,315 1,241,359 413,964 113,714 248,341 2002 Actual

6,969 56,315 1,241,359 413,964 113,714 253,005 2002 Typical

11,643 59,934 889,957 448,625 90,390 282,307 2009 SC

14,975 68,415 663,493 481,332 83,167 282,307 2018

7,084 115,264 1,917,842 505,163 89,828 4,302 2002 Actual

6,787 115,264 1,917,842 505,163 89,828 10,124 2002 Typical

7,214 119,216 1,338,016 554,121 74,189 17,372 2009 TN

7,723 140,556 976,634 593,100 68,809 18,860 2018

6,892 63,796 2,163,259 660,105 155,873 15,625 2002 Actual

6,797 63,784 2,163,259 660,105 155,873 12,611 2002 Typical

12,535 68,326 1,453,946 726,815 128,132 21,130 2009 VA

18,850 76,846 1,075,104 797,683 121,690 26,923 2018

10,341 89,879 533,471 133,113 39,546 6,738 2002 Actual

10,117 89,878 533,471 133,113 39,546 2,652 2002 Typical

11,493 93,839 365,549 152,862 31,640 3,949 2009 WV

12,397 111,302 274,804 167,424 28,773 5,013 2018Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix AMACTEC, Inc.201Annual NH3Emissions by Source Sector050,000100,000150,000200,000250,000 AL F L GA K Y MS NC S C TN V A WV

Tons per yearFIRESAREANONROADONROADNONEGUEGU2002 Actual EGU and Fires2002 Typical EGU and Fires20092018

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix A MACTEC, Inc. 

# 202 

# Annual NH 3 

# Emissions by Source Sector

Name EGU NONEGU ONROAD NONROAD AREA FIRES YEAR

317 1,883 5,588 33 58,318 1,689 2002 Actual

239 1,883 5,588 33 58,318 1,957 2002 Typical

359 2,132 6,364 36 64,268 2,050 2009 AL

1,072 2,464 7,298 42 71,915 2,054 2018

234 1,423 18,114 134 37,446 3,102 2002 Actual

222 1,423 18,114 134 37,446 3,157 2002 Typical

1,629 1,544 21,781 148 38,616 3,157 2009 FL

2,976 1,829 26,163 171 40,432 3,157 2018

83 3,613 10,546 60 80,913 2,578 2002 Actual

86 3,613 10,546 60 80,913 2,153 2002 Typical

686 3,963 12,687 68 89,212 2,229 2009 GA

1,677 4,797 14,873 79 99,885 2,229 2018

326 674 5,055 31 51,135 39 2002 Actual

321 674 5,055 31 51,135 112 2002 Typical

400 760 5,796 34 53,005 143 2009 KY

476 901 7,811 40 55,211 150 2018

190 1,169 3,585 23 58,721 59 2002 Actual

198 1,169 3,585 23 58,721 65 2002 Typical

334 668 4,035 25 63,708 217 2009 MS

827 764 4,566 29 69,910 225 2018

54 1,179 9,702 65 161,860 155 2002 Actual

55 1,179 9,702 65 161,860 324 2002 Typical

445 1,285 11,825 72 170,314 433 2009 NC

663 1,465 14,065 83 180,866 501 2018

142 1,411 4,694 33 28,166 980 2002 Actual

141 1,411 4,694 33 28,166 908 2002 Typical

370 1,578 5,523 36 30,555 1,039 2009 SC

625 1,779 6,473 41 33,496 1,039 2018

204 1,613 6,625 43 34,393 19 2002 Actual

197 1,613 6,625 43 34,393 46 2002 Typical

227 1,840 7,782 48 35,253 78 2009 TN

241 2,213 9,021 55 36,291 85 2018

127 3,104 7,852 48 43,905 70 2002 Actual

130 3,104 7,852 48 43,905 57 2002 Typical

694 3,045 9,086 53 46,639 95 2009 VA

606 3,604 10,624 61 50,175 121 2018

121 332 1,908 9 9,963 30 2002 Actual

121 332 1,908 9 9,963 12 2002 Typical

330 314 2,148 11 10,625 18 2009 WV

143 378 2,497 13 11,504 23 2018Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix AMACTEC, Inc.203Annual NOx Emissions by Source Sector0200,000400,000600,000800,0001,000,0001,200,000 A L FL GA KY MS N C SC TN V A W V

Tons per yearFIRESAREANONROADONROADNONEGUEGU2002 Actual EGU and Fires2002 Typical EGU and Fires20092018v

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix A MACTEC, Inc. 

# 204 

# Annual NO

x 

# Emissions by Source Sector

Name EGU NONEGU ONROAD NONROAD AREA FIRES YEAR

161,038 83,310 158,212 65,366 23,444 10,728 2002 Actual

154,704 83,302 158,212 65,366 23,444 11,456 2002 Typical

82,305 69,409 101,831 56,862 23,930 11,901 2009 AL

64,358 77,960 47,298 43,799 25,028 11,918 2018

257,677 45,156 465,640 180,627 28,872 15,942 2002 Actual

255,678 45,150 465,640 180,627 28,872 19,791 2002 Typical

132,535 47,125 315,840 163,794 28,187 19,791 2009 FL

87,645 52,959 150,180 127,885 30,708 19,791 2018

147,517 49,251 307,732 97,961 36,142 14,203 2002 Actual

148,126 49,251 307,732 97,961 36,142 13,882 2002 Typical

98,497 50,353 209,349 85,733 37,729 14,243 2009 GA

69,856 55,824 102,179 64,579 41,332 14,243 2018

198,817 38,392 156,417 104,571 39,507 187 2002 Actual

201,928 38,434 156,417 104,571 39,507 534 2002 Typical

97,263 37,758 101,182 94,752 42,088 682 2009 KY

64,378 41,034 52,263 79,392 44,346 714 2018

43,135 61,526 111,914 88,787 4,200 283 2002 Actual

40,433 61,553 111,914 88,787 4,200 308 2002 Typical

47,276 56,398 70,743 80,567 4,249 1,033 2009 MS

21,535 61,252 30,619 68,252 4,483 1,073 2018

151,850 44,929 327,329 84,284 36,550 740 2002 Actual

148,812 44,929 327,329 84,284 36,550 1,544 2002 Typical

66,521 34,768 201,609 70,997 39,954 2,065 2009 NC

61,110 37,802 87,791 49,046 43,865 2,387 2018

88,241 42,153 140,489 50,249 19,332 4,932 2002 Actual

88,528 42,153 140,489 50,249 19,332 5,270 2002 Typical

48,668 39,368 92,499 43,235 19,360 5,899 2009 SC

51,751 43,331 43,490 31,758 20,592 5,899 2018

157,307 64,344 238,577 96,827 17,844 92 2002 Actual

152,137 64,344 238,577 96,827 17,844 217 2002 Typical

66,405 57,514 151,912 86,641 18,499 373 2009 TN

31,715 62,519 69,385 70,226 19,597 405 2018

86,886 60,415 222,374 63,219 51,418 335 2002 Actual

85,081 60,390 222,374 63,219 51,418 271 2002 Typical

64,358 51,001 134,232 54,993 52,618 453 2009 VA

64,344 55,734 63,342 40,393 56,158 578 2018

230,977 46,612 58,999 33,239 12,687 145 2002 Actual

222,437 46,618 58,999 33,239 12,687 57 2002 Typical

85,476 38,023 35,635 30,133 13,439 85 2009 WV

51,474 43,280 17,247 25,710 14,828 108 2018Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix AMACTEC, Inc.205Annual PM10Emissions by Source Sector0200,000400,000600,000800,0001,000,0001,200,000 A L FL GA KY MS N C SC TN V A W V

Tons per yearFIRESAREANONROADONROADNONEGUEGU2002 Actual EGU and Fires2002 Typical EGU and Fires20092018

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix A MACTEC, Inc. 

# 206 

# Annual PM 10 

# Emissions by Source Sector

Name EGU NONEGU ONROAD NONROAD AREA FIRES YEAR

7,646 25,240 3,903 4,787 393,588 47,237 2002 Actual

7,845 25,239 3,903 4,787 393,588 50,833 2002 Typical

6,969 25,421 3,171 4,027 413,020 52,851 2009 AL

7,822 29,889 2,410 3,041 445,256 52,927 2018

21,387 35,857 11,275 18,281 443,346 85,263 2002 Actual

21,391 35,856 11,275 18,281 443,346 98,470 2002 Typical

20,182 39,947 9,911 15,613 503,230 98,470 2009 FL

12,791 46,492 8,268 12,497 578,516 98,470 2018

11,224 21,610 7,246 8,618 695,414 65,227 2002 Actual

11,467 21,610 7,246 8,618 695,414 62,336 2002 Typical

17,891 23,103 6,072 7,521 776,411 63,973 2009 GA

20,732 27,273 4,844 6,015 880,199 63,973 2018

4,701 16,626 3,723 6,425 233,559 846 2002 Actual

4,795 16,626 3,723 6,425 233,559 2,421 2002 Typical

6,463 17,174 2,976 5,544 242,177 3,093 2009 KY

6,694 20,153 2,580 4,556 256,052 3,237 2018

1,633 19,472 2,859 5,010 343,377 1,284 2002 Actual

1,706 19,469 2,859 5,010 343,377 1,396 2002 Typical

5,182 19,245 2,275 4,270 356,324 4,683 2009 MS

7,412 22,837 1,624 3,452 375,495 4,865 2018

22,754 13,838 6,579 7,348 280,379 3,356 2002 Actual

22,994 13,838 6,579 7,348 280,379 6,998 2002 Typical

22,152 13,910 5,572 6,055 292,443 9,359 2009 NC

35,275 15,737 4,392 4,298 315,294 10,819 2018

21,400 14,142 3,452 4,152 260,858 25,968 2002 Actual

21,827 14,142 3,452 4,152 260,858 26,304 2002 Typical

20,041 12,959 2,862 3,471 278,299 29,153 2009 SC

27,640 14,674 2,184 2,617 304,251 29,153 2018

14,640 35,174 5,371 6,819 212,554 418 2002 Actual

13,866 35,174 5,371 6,819 212,554 984 2002 Typical

15,608 34,581 4,206 5,877 226,098 1,689 2009 TN

15,941 41,999 3,092 4,672 246,252 1,834 2018

3,960 13,252 4,549 8,728 237,577 1,519 2002 Actual

3,892 13,252 4,549 8,728 237,577 1,226 2002 Typical

5,606 13,046 3,747 7,510 252,488 2,054 2009 VA

12,551 15,111 3,212 6,208 275,351 2,618 2018

4,573 17,503 1,381 1,850 115,346 655 2002 Actual

4,472 17,503 1,381 1,850 115,346 258 2002 Typical

5,657 11,882 1,068 1,640 115,089 384 2009 WV

5,784 14,202 819 1,292 121,549 487 2018Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix AMACTEC, Inc.207Annual PM2.5Emissions by Source Sector050,000100,000150,000200,000250,000 AL F L GA K Y MS NC S C TN V A WV

Tons per yearFIRESAREANONROADONROADNONEGUEGU2002 Actual EGU and Fires2002 Typical EGU and Fires20092018

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix A MACTEC, Inc. 

# 208 

# Annual PM 2.5 

# Emissions by Source Sector

Name EGU NONEGU ONROAD NONROAD AREA FIRES YEAR

4,113 19,178 2,799 4,502 56,654 42,041 2002 Actual

4,176 19,177 2,799 4,502 56,654 44,812 2002 Typical

AL 3,921 19,230 2,032 3,776 58,699 46,543 2009

4,768 22,584 1,192 2,835 62,323 46,608 2018

15,643 30,504 7,868 17,415 58,878 75,717 2002 Actual

15,575 30,504 7,868 17,415 58,878 88,756 2002 Typical

FL 14,790 34,019 6,173 14,866 64,589 88,756 2009

9,417 39,486 4,038 11,868 72,454 88,756 2018

4,939 17,462 5,168 8,226 103,794 57,293 2002 Actual

5,070 17,462 5,168 8,226 103,794 55,712 2002 Typical

GA 10,907 18,982 3,840 7,175 112,001 57,116 2009

13,881 22,416 2,380 5,730 123,704 57,116 2018

2,802 11,372 2,697 6,046 45,453 726 2002 Actual

2,847 11,372 2,697 6,046 45,453 2,076 2002 Typical

KY 4,279 11,686 1,920 5,203 46,243 2,653 2009

4,434 13,739 1,272 4,256 47,645 2,777 2018

1,138 9,906 2,112 4,690 50,401 1,102 2002 Actual

1,147 9,902 2,112 4,690 50,401 1,197 2002 Typical

MS 4,996 9,199 1,508 3,985 51,661 4,016 2009

7,252 10,719 819 3,203 53,222 4,173 2018

16,498 10,500 4,623 7,005 64,052 2,878 2002 Actual

16,623 10,500 4,623 7,005 64,052 6,002 2002 Typical

NC 15,949 10,458 3,493 5,760 69,457 8,027 2009

28,137 11,825 2,123 4,069 71,262 9,279 2018

17,154 10,245 2,501 3,945 40,291 22,953 2002 Actual

17,521 10,245 2,501 3,945 40,291 23,511 2002 Typical

SC 16,548 9,048 1,855 3,294 41,613 25,955 2009

23,794 10,699 1,087 2,474 44,319 25,955 2018

12,166 27,807 3,949 6,458 42,566 359 2002 Actual

11,491 27,807 3,949 6,458 42,566 844 2002 Typical

TN 13,092 27,367 2,751 5,557 44,124 1,449 2009

13,387 33,293 1,544 4,403 46,692 1,573 2018

2,606 10,165 3,102 8,288 43,989 1,303 2002 Actual

2,650 10,165 3,102 8,288 43,989 1,052 2002 Typical

VA 4,165 9,988 2,241 7,136 44,514 1,762 '2009

10,773 11,605 1,543 5,891 46,697 2,245 2018

2,210 13,313 995 1,728 21,049 562 2002 Actual

2,163 13,313 995 1,728 21,049 221 2002 Typical

WV 2,940 7,638 684 1,528 20,664 329 2009

3,116 9,124 405 1,198 21,490 418 2018Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix AMACTEC, Inc.209Annual SO2Emissions by Source Sector0100,000200,000300,000400,000500,000600,000700,000 AL F L GA K Y MS NC S C TN V A WV

Tons per yearFIRESAREANONROADONROADNONEGUEGU2002 Actual EGU and Fires2002 Typical EGU and Fires20092018

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Appendix A MACTEC, Inc. 

# 210 

# Annual SO 2 

# Emissions by Source Sector

Name EGU NONEGU ONROAD NONROAD AREA FIRES YEAR

447,828 96,481 6,900 7,584 52,253 2,208 2002 Actual

423,736 96,481 6,900 7,584 52,253 2,559 2002 Typical

378,052 101,246 810 3,471 48,228 2,681 2009 AL

135,851 103,303 720 2,818 50,264 2,686 2018

453,631 65,090 20,915 20,614 40,491 4,057 2002 Actual

444,383 65,090 20,915 20,614 40,491 4,129 2002 Typical

291,831 65,651 2,612 8,967 36,699 4,129 2009 FL

194,028 71,810 2,533 7,536 38,317 4,129 2018

514,952 53,774 12,184 9,005 57,559 3,372 2002 Actual

517,633 53,778 12,184 9,005 57,559 2,815 2002 Typical

408,679 53,983 1,585 2,725 57,696 2,914 2009 GA

68,515 59,343 1,457 1,709 59,729 2,914 2018

484,057 34,029 6,308 14,043 41,805 51 2002 Actual

495,153 34,029 6,308 14,043 41,805 146 2002 Typical

271,669 36,418 759 9,180 43,087 187 2009 KY

222,102 40,682 763 8,592 44,186 196 2018

67,429 35,960 4,614 11,315 771 78 2002 Actual

60,086 35,954 4,614 11,315 771 84 2002 Typical

76,646 25,564 537 7,191 753 283 2009 MS

15,213 25,674 440 6,638 746 294 2018

477,990 44,123 12,420 7,693 5,412 203 2002 Actual

478,488 44,123 12,420 7,693 5,412 423 2002 Typical

242,286 42,536 1,503 1,892 5,751 566 2009 NC

120,165 46,314 1,481 905 6,085 655 2018

206,399 53,518 5,972 4,866 12,900 1,281 2002 Actual

210,272 53,518 5,972 4,866 12,900 1,187 2002 Typical

129,122 47,193 721 1,701 13,051 1,359 2009 SC

95,377 52,410 643 1,198 13,457 1,359 2018

334,151 79,604 9,226 10,441 29,917 25 2002 Actual

320,146 79,604 9,226 10,441 29,917 60 2002 Typical

255,410 64,964 1,076 5,651 30,577 102 2009 TN

112,672 56,682 948 5,207 31,962 111 2018

241,204 63,903 8,294 8,663 105,890 92 2002 Actual

233,691 63,900 8,294 8,663 105,890 74 2002 Typical

174,777 58,039 1,079 1,707 105,984 124 2009 VA

98,988 57,790 1,043 507 109,380 158 2018

516,084 54,070 2,464 2,112 11,667 40 2002 Actual

500,381 54,077 2,464 2,112 11,667 16 2002 Typical

268,952 55,598 279 359 12,284 23 2009 WV

106,199 61,702 253 56 12,849 29 2018Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix AMACTEC, Inc.211Annual VOC Emissions by Source Sector0200,000400,000600,000800,0001,000,0001,200,0001,400,000 A L FL GA KY MS N C SC TN V A W V

Tons per yearFIRESAREANONROADONROADNONEGUEGU2002 Actual EGU and Fires2002 Typical EGU and Fires20092018

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Appendix A MACTEC, Inc. 

# 212 

# Annual VOC Emissions by Source Sector

Name EGU NONEGU ONROAD NONROAD AREA FIRES YEAR

2,295 47,037 127,295 60,487 182,674 25,278 2002 Actual

2,288 47,035 127,295 60,487 182,674 26,526 2002 Typical

2,473 46,644 76,990 50,249 143,454 27,502 2009 AL

2,952 54,291 49,175 40,407 153,577 27,539 2018

2,524 38,471 527,209 272,072 404,302 42,724 2002 Actual

2,531 38,471 527,209 272,072 404,302 51,527 2002 Typical

2,730 36,882 340,947 209,543 420,172 51,527 2009 FL

3,047 42,813 222,303 183,452 489,975 51,527 2018

1,244 33,709 283,421 85,965 299,679 33,979 2002 Actual

1,256 33,709 283,421 85,965 299,679 33,918 2002 Typical

2,314 34,116 195,125 67,686 272,315 34,710 2009 GA

2,816 40,282 109,763 56,761 319,328 34,710 2018

1,487 44,834 103,503 44,805 95,375 410 2002 Actual

1,481 44,834 103,503 44,805 95,375 1,172 2002 Typical

1,369 47,786 73,942 38,558 94,042 1,497 2009 KY

1,426 55,861 47,066 30,920 103,490 1,567 2018

648 43,204 87,672 41,081 131,808 622 2002 Actual

629 43,203 87,672 41,081 131,808 675 2002 Typical

564 37,747 52,107 36,197 124,977 2,266 2009 MS

1,274 45,335 31,616 28,842 140,134 2,355 2018

988 61,182 263,766 94,480 237,926 1,624 2002 Actual

986 61,182 263,766 94,480 237,926 3,387 2002 Typical

954 61,925 168,676 74,056 187,769 4,530 2009 NC

1,302 70,875 101,099 61,327 189,591 5,236 2018

470 38,458 116,163 55,016 161,000 14,202 2002 Actual

470 38,458 116,163 55,016 161,000 14,666 2002 Typical

723 34,403 72,603 43,061 146,107 16,045 2009 SC

931 41,987 46,301 36,131 161,228 16,045 2018

926 84,328 179,807 66,450 153,307 202 2002 Actual

890 84,328 179,807 66,450 153,307 476 2002 Typical

932 73,498 115,181 55,358 154,377 817 2009 TN

976 92,456 67,324 45,084 182,222 888 2018

754 43,152 159,790 74,866 174,116 735 2002 Actual

747 43,152 159,790 74,866 174,116 593 2002 Typical

788 43,726 96,770 57,009 147,034 994 2009 VA

980 53,186 61,964 49,052 150,919 1,267 2018

1,180 14,595 42,174 18,566 60,443 317 2002 Actual

1,140 14,595 42,174 18,566 60,443 125 2002 Typical

1,361 13,043 24,843 18,069 55,288 186 2009 WV

1,387 15,582 16,121 14,086 60,747 236 2018

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix B MACTEC, Inc. 

# 213 

# APPENDIX B:

STATE VMT TOTALS

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix B MACTEC, Inc. 

# 214 

# State VMT Totals

Million Miles Per Year

2002 LDGV LDGT1 LDGT2 HDDV LDDV LDDT HDDV MC TOTAL

AL 31,982 12,728 4,347 1,630 63 69 4,709 196 55,723

FL 105,340 40,835 13,945 5,079 206 220 12,465 591 178,681

GA 61,660 24,394 8,331 3,103 121 132 8,673 371 106,785

KY 28,751 12,189 3,366 1,606 55 55 4,827 171 51,020

MS 23,933 6,724 439 1,025 330 125 3,610 92 36,278

NC 51,189 30,339 10,787 4,119 230 230 9,440 461 106,795

SC 26,672 10,750 3,671 1,395 52 58 4,306 171 47,074

TN 30,809 20,272 6,922 2,943 52 111 6,810 397 68,316

VA 36,336 24,784 8,667 2,148 61 139 4,969 369 77,472

WV 9,010 5,931 2,028 732 25 37 1,664 117 19,544

2009 LDGV LDGT1 LDGT2 HDDV LDDV LDDT HDDV MC TOTAL

AL 30,638 18,598 5,511 2,069 65 72 5,976 249 63,178

FL 107,641 62,449 18,697 6,820 215 230 16,743 794 213,590

GA 61,569 36,641 10,933 4,077 126 137 11,374 487 125,343

KY 28,006 16,984 4,428 1,983 58 57 5,983 231 57,729

MS 23,641 10,131 573 1,341 356 135 4,719 120 41,017

NC 48,495 43,484 15,122 4,576 40 224 10,928 527 123,396

SC 26,451 16,119 4,796 1,824 55 61 5,617 223 55,147

TN 28,775 28,650 8,521 3,627 52 111 8,391 490 78,615

VA 33,663 34,814 10,597 2,624 61 137 6,073 451 88,419

WV 8,128 8,205 2,427 878 25 37 1,995 140 21,835

2018 LDGV LDGT1 LDGT2 HDDV LDDV LDDT HDDV MC TOTAL

AL 31,706 23,562 6,990 2,634 67 84 7,607 317 72,966

FL 116,576 83,385 24,996 9,156 221 301 22,491 1,066 258,191

GA 65,214 47,687 14,245 5,332 129 171 14,853 637 148,269

KY 29,353 21,058 5,558 2,463 60 66 7,454 288 66,300

MS 24,787 12,984 736 1,727 372 159 6,076 155 46,996

NC 42,247 51,568 18,260 4,985 279 279 11,396 553 129,566

SC 27,930 20,880 6,220 2,375 57 75 7,306 290 65,133

TN 29,253 35,702 10,629 4,538 52 130 10,500 613 91,417

VA 35,030 44,438 13,543 3,358 62 164 7,770 578 104,944

WV 8,130 10,025 2,969 1,078 25 41 2,451 172 24,891

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix C MACTEC, Inc. 

# 215 

# APPENDIX C:

STATE TIER 1 EMISSION TOTALS

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix C MACTEC, Inc. 

# 216 

# State Tier 1 Emission Totals

State Year TIER1 TIER 1 NAME CO NH3 NOX PM10 PM2.5 SO2 VOC

AL 2002 01 FUEL COMB. ELEC. UTIL. 11,279 317 161,038 7,646 4,113 447,828 2,295

AL 2002 02 FUEL COMB. INDUSTRIAL 67,132 234 51,535 6,730 3,792 40,918 2,239

AL 2002 03 FUEL COMB. OTHER 70,498 169 19,237 6,411 5,528 39,606 56,120

AL 2002 04 CHEMICAL & ALLIED PRODUCT

MFG 5,721 35 2,032 1,220 888 12,770 7,273

AL 2002 05 METALS PROCESSING 38,247 376 6,011 9,107 7,803 14,039 3,299

AL 2002 06 PETROLEUM & RELATED

INDUSTRIES 13,606 0 878 194 155 22,991 4,024

AL 2002 07 OTHER INDUSTRIAL PROCESSES 47,676 1,468 25,252 22,689 9,516 17,904 25,304

AL 2002 08 SOLVENT UTILIZATION 216 0 226 149 126 3 108,437

AL 2002 09 STORAGE & TRANSPORT 174 0 230 1,086 636 13 16,522

AL 2002 10 WASTE DISPOSAL & RECYCLING 104,914 10 4,016 15,832 14,946 489 12,612

AL 2002 11 HIGHWAY VEHICLES 1,321,528 5,588 158,212 3,903 2,799 6,900 127,295

AL 2002 12 OFF-HIGHWAY 414,385 33 65,366 4,787 4,502 7,584 60,487

AL 2002 14 MISCELLANEOUS 385,005 59,596 8,065 402,646 74,483 2,208 19,161

2002

Total 2,480,381 67,827 502,098 482,402 129,287 613,255 445,065

AL 2009 01 FUEL COMB. ELEC. UTIL. 14,986 359 82,305 6,969 3,921 378,052 2,473

AL 2009 02 FUEL COMB. INDUSTRIAL 68,146 274 36,301 6,140 3,438 40,651 2,191

AL 2009 03 FUEL COMB. OTHER 52,256 158 19,514 5,904 5,104 36,048 31,403

AL 2009 04 CHEMICAL & ALLIED PRODUCT

MFG 6,118 38 2,273 1,257 912 13,660 6,613

AL 2009 05 METALS PROCESSING 38,969 500 6,021 9,062 7,756 16,629 3,305

AL 2009 06 PETROLEUM & RELATED

INDUSTRIES 13,241 0 858 221 177 22,495 3,336

AL 2009 07 OTHER INDUSTRIAL PROCESSES 52,004 1,571 26,340 24,196 10,197 19,383 26,519

AL 2009 08 SOLVENT UTILIZATION 247 0 257 165 139 4 92,631

AL 2009 09 STORAGE & TRANSPORT 192 0 253 1,146 584 14 17,738

AL 2009 10 WASTE DISPOSAL & RECYCLING 87,225 11 3,634 14,504 13,485 590 11,207

AL 2009 11 HIGHWAY VEHICLES 915,647 6,364 101,831 3,171 2,032 810 76,990

AL 2009 12 OFF-HIGHWAY 454,686 36 56,862 4,027 3,776 3,471 50,249

AL 2009 14 MISCELLANEOUS 463,498 65,899 9,788 428,698 82,679 2,681 22,657

2009

Total 2,167,216 75,209 346,238 505,457 134,201 534,489 347,312

AL 2018 01 FUEL COMB. ELEC. UTIL. 24,342 1,072 64,358 7,822 4,768 135,851 2,952

AL 2018 02 FUEL COMB. INDUSTRIAL 69,068 275 38,424 6,427 3,599 40,126 2,293

AL 2018 03 FUEL COMB. OTHER 43,744 164 20,185 5,641 4,818 37,162 21,215

AL 2018 04 CHEMICAL & ALLIED PRODUCT

MFG 7,384 46 2,804 1,523 1,106 16,509 8,040

AL 2018 05 METALS PROCESSING 49,770 674 7,519 11,036 9,423 21,824 4,234

AL 2018 06 PETROLEUM & RELATED

INDUSTRIES 13,002 0 848 258 207 15,364 3,421

AL 2018 07 OTHER INDUSTRIAL PROCESSES 60,452 1,732 30,831 27,727 11,812 21,843 30,267

AL 2018 08 SOLVENT UTILIZATION 301 0 317 200 169 4 112,412

AL 2018 09 STORAGE & TRANSPORT 234 0 307 1,366 699 17 18,900

AL 2018 10 WASTE DISPOSAL & RECYCLING 88,758 13 3,867 15,343 14,143 718 11,938

AL 2018 11 HIGHWAY VEHICLES 676,210 7,298 47,298 2,410 1,192 720 49,175

AL 2018 12 OFF-HIGHWAY 488,924 42 43,799 3,041 2,835 2,818 40,407

AL 2018 14 MISCELLANEOUS 464,235 73,529 9,803 458,551 85,538 2,686 22,686

2018

Total 1,986,424 84,845 270,362 541,346 140,310 295,642 327,940

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix C MACTEC, Inc. 

# 217 

# State Tier 1 Emission Totals

State Year TIER1 TIER 1 NAME CO NH3 NOX PM10 PM2.5 SO2 VOC

FL 2002 01 FUEL COMB. ELEC. UTIL. 57,113 234 257,677 21,387 15,643 453,631 2,524

FL 2002 02 FUEL COMB. INDUSTRIAL 64,798 131 45,157 20,442 18,547 42,524 4,219

FL 2002 03 FUEL COMB. OTHER 49,230 99 11,597 8,464 8,074 20,031 16,123

FL 2002 04 CHEMICAL & ALLIED

PRODUCT MFG 745 1,101 2,221 1,868 1,488 34,462 3,542

FL 2002 05 METALS PROCESSING 1,404 1 194 449 334 882 82

FL 2002 06 PETROLEUM & RELATED

INDUSTRIES 1,070 0 560 259 129 470 724

FL 2002 07 OTHER INDUSTRIAL

PROCESSES 18,586 19 12,325 23,419 11,844 6,515 27,024

FL 2002 08 SOLVENT UTILIZATION 0 0 1 128 110 0 304,582

FL 2002 09 STORAGE & TRANSPORT 161 0 561 1,645 720 38 79,281

FL 2002 10 WASTE DISPOSAL &

RECYCLING 54,721 351 2,535 9,943 9,405 659 9,125

FL 2002 11 HIGHWAY VEHICLES 4,550,447 18,114 465,640 11,275 7,868 20,915 527,209

FL 2002 12 OFF-HIGHWAY 1,920,729 134 180,627 18,281 17,415 20,614 272,072

FL 2002 14 MISCELLANEOUS 752,915 40,269 14,821 497,846 114,447 4,057 40,795

2002

Total 7,471,920 60,454 993,915 615,407 206,025 604,797 1,287,301

FL 2009 01 FUEL COMB. ELEC. UTIL. 35,928 1,631 86,165 9,007 5,910 186,055 1,910

FL 2009 02 FUEL COMB. INDUSTRIAL 69,972 146 44,480 16,265 14,827 38,225 4,473

FL 2009 03 FUEL COMB. OTHER 33,014 100 10,800 7,555 7,174 19,882 10,907

FL 2009 04 CHEMICAL & ALLIED

PRODUCT MFG 901 1,231 2,461 1,908 1,526 34,961 3,821

FL 2009 05 METALS PROCESSING 1,545 1 176 361 251 993 82

FL 2009 06 PETROLEUM & RELATED

INDUSTRIES 1,190 0 612 304 156 519 748

FL 2009 07 OTHER INDUSTRIAL

PROCESSES 18,593 26 13,521 33,084 19,357 6,881 26,413

FL 2009 08 SOLVENT UTILIZATION 0 0 1 132 113 0 319,723

FL 2009 09 STORAGE & TRANSPORT 187 0 621 1,661 727 50 83,880

FL 2009 10 WASTE DISPOSAL &

RECYCLING 177,953 342 6,251 22,971 22,364 698 17,241

FL 2009 11 HIGHWAY VEHICLES 3,308,863 21,549 312,321 9,801 6,104 2,584 336,707

FL 2009 12 OFF-HIGHWAY 2,104,920 148 163,794 15,613 14,866 8,967 209,543

FL 2009 14 MISCELLANEOUS 764,004 41,471 15,075 557,331 120,796 4,129 41,290

2009

Total 6,596,484 66,874 707,273 687,353 223,192 406,888 1,061,801

FL 2018 01 FUEL COMB. ELEC. UTIL. 85,495 2,976 87,645 12,791 9,417 194,028 3,047

FL 2018 02 FUEL COMB. INDUSTRIAL 77,465 156 48,879 17,876 16,324 37,205 4,894

FL 2018 03 FUEL COMB. OTHER 27,094 110 12,356 7,255 6,853 20,975 8,879

FL 2018 04 CHEMICAL & ALLIED

PRODUCT MFG 1,200 1,448 3,119 2,367 1,907 41,395 4,739

FL 2018 05 METALS PROCESSING 1,973 2 225 466 323 1,325 106

FL 2018 06 PETROLEUM & RELATED

INDUSTRIES 1,513 0 778 387 198 659 918

FL 2018 07 OTHER INDUSTRIAL

PROCESSES 20,748 35 15,855 39,842 23,289 7,741 29,716

FL 2018 08 SOLVENT UTILIZATION 0 0 1 158 135 0 387,657

FL 2018 09 STORAGE & TRANSPORT 226 0 690 2,004 877 58 87,732

FL 2018 10 WASTE DISPOSAL &

RECYCLING 180,730 418 6,486 24,140 23,427 769 18,335

FL 2018 11 HIGHWAY VEHICLES 2,554,160 26,163 150,180 8,268 4,038 2,533 222,303

FL 2018 12 OFF-HIGHWAY 2,323,327 171 127,885 12,497 11,868 7,536 183,452

FL 2018 14 MISCELLANEOUS 763,701 43,251 15,068 628,984 127,364 4,129 41,338

2018

Total 6,037,633 74,728 469,168 757,033 226,019 318,353 993,116

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix C MACTEC, Inc. 

# 218 

# State Tier 1 Emission Totals

State Year TIER1 TIER 1 NAME CO NH3 NOX PM10 PM2.5 SO2 VOC

GA 2002 01 FUEL COMB. ELEC. UTIL. 9,712 83 147,517 11,224 4,939 514,952 1,244

GA 2002 02 FUEL COMB. INDUSTRIAL 59,492 27 53,039 12,037 7,886 88,791 3,956

GA 2002 03 FUEL COMB. OTHER 63,314 17 14,465 10,142 10,057 10,740 27,226

GA 2002 04 CHEMICAL & ALLIED PRODUC T MFG 5,387 920 2,277 391 305 2,721 2,668

GA 2002 05 METALS PROCESSING 330 0 60 147 94 0 70

GA 2002 06 PETROLEUM & RELATED INDUSTRIES 41 0 3 69 44 68 175

GA 2002 07 OTHER INDUSTRIAL PROCESSES 27,960 2,666 12,215 39,630 13,073 8,701 26,999

GA 2002 08 SOLVENT UTILIZATION 4 0 22 13 13 0 234,744

GA 2002 09 STORAGE & TRANSPORT 39 0 6 583 360 0 26,334

GA 2002 10 WASTE DISPOSAL & RECYCLING 146,183 16 5,164 23,422 22,506 312 15,003

GA 2002 11 HIGHWAY VEHICLES 2,735,968 10,546 307,732 7,246 5,168 12,184 283,421

GA 2002 12 OFF-HIGHWAY 791,158 60 97,961 8,618 8,226 9,005 85,965

GA 2002 14 MISCELLANEOUS 590,400 83,458 12,308 695,723 124,142 3,372 29,640

2002

Total 4,429,989 97,795 652,769 809,244 196,815 650,846 737,444

GA 2009 01 FUEL COMB. ELEC. UTIL. 23,721 686 98,497 17,891 10,907 408,679 2,314

GA 2009 02 FUEL COMB. INDUSTRIAL 63,067 28 53,726 11,206 7,390 89,850 4,163

GA 2009 03 FUEL COMB. OTHER 45,184 17 15,347 8,496 8,400 10,981 15,683

GA 2009 04 CHEMICAL & ALLIED PRODUC T MFG 6,044 1,032 2, 531 436 341 2,743 2,814

GA 2009 05 METALS PROCESSING 363 0 61 159 100 0 47

GA 2009 06 PETROLEUM & RELATED INDUSTRIES 50 0 4 83 54 82 154

GA 2009 07 OTHER INDUSTRIAL PROCESSES 29,976 2,902 12,528 45,339 14,758 7,662 28,441

GA 2009 08 SOLVENT UTILIZATION 4 0 25 14 14 0 216,248

GA 2009 09 STORAGE & TRANSPORT 45 0 7 649 401 0 27,821

GA 2009 10 WASTE DISPOSAL & RECYCLING 218,460 18 7,419 31,955 30,900 360 18,711

GA 2009 11 HIGHWAY VEHICLES 1,983,803 12,687 209,349 6,072 3,840 1,585 195,125

GA 2009 12 OFF-HIGHWAY 882,970 68 85,733 7,521 7,175 2,725 67,686

GA 2009 14 MISCELLANEOUS 515,329 91,406 10,637 765,043 125,665 2,914 26,388

2009

Total 3,769,016 108,844 495,864 894,865 209,944 527,582 605,595

GA 2018 01 FUEL COMB. ELEC. UTIL. 44,269 1,677 69,856 20,732 13,881 68,515 2,816

GA 2018 02 FUEL COMB. INDUSTRIAL 67,067 30 57,232 11,755 7,769 94,403 4,424

GA 2018 03 FUEL COMB. OTHER 39,440 17 17,801 7,722 7,622 11,958 11,482

GA 2018 04 CHEMICAL & ALLIED PRODUC T MFG 7,076 1,208 2, 982 517 405 3,436 3,524

GA 2018 05 METALS PROCESSING 421 0 76 185 118 0 55

GA 2018 06 PETROLEUM & RELATED INDUSTRIES 63 0 5 105 68 104 191

GA 2018 07 OTHER INDUSTRIAL PROCESSES 33,611 3,559 14,460 55,130 17,899 8,748 33,333

GA 2018 08 SOLVENT UTILIZATION 5 0 30 22 22 0 264,326

GA 2018 09 STORAGE & TRANSPORT 54 0 9 764 470 0 29,409

GA 2018 10 WASTE DISPOSAL & RECYCLING 235,690 22 8,120 35,280 34,038 423 20,411

GA 2018 11 HIGHWAY VEHICLES 1,476,981 14,873 102,179 4,844 2,380 1,457 109,763

GA 2018 12 OFF-HIGHWAY 973,872 79 64,579 6,015 5,730 1,709 56,761

GA 2018 14 MISCELLANEOUS 515,220 102,075 10,635 859,835 134,730 2,914 26,368

2018

Total 3,393,769 123,540 347,964 1,002,907 225,133 193,668 562,862

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix C MACTEC, Inc. 

# 220 

# State Tier 1 Emission Totals

State Year TIER1 TIER 1 NAME CO NH3 NOX PM10 PM2.5 SO2 VOC

KY 2002 01 FUEL COMB. ELEC. UTIL. 12,619 326 198,817 4,701 2,802 484,057 1,487

KY 2002 02 FUEL COMB. INDUSTRIAL 14,110 182 60,674 2,155 1,463 41,825 1,565

KY 2002 03 FUEL COMB. OTHER 40,806 55 4,997 7,679 7,352 9,647 12,711

KY 2002 04 CHEMICAL & ALLIED PRODUCT MFG 176 214 296 774 581 2,345 3,462

KY 2002 05 METALS PROCESSING 89,197 6 1,082 3,396 2,720 12,328 1,508

KY 2002 06 PETROLEUM & RELATED

INDUSTRIES 4,304 335 2,519 308 205 5,747 2,895

KY 2002 07 OTHER INDUSTRIAL PROCESSES 6,493 78 6,518 31,429 10,394 3,333 25,388

KY 2002 08 SOLVENT UTILIZATION 0 10 9 317 241 1 61,834

KY 2002 09 STORAGE & TRANSPORT 33 8 15 1,920 1,177 3 18,853

KY 2002 10 WASTE DISPOSAL & RECYCLING 20,622 8 1,768 7,229 6,476 606 7,927

KY 2002 11 HIGHWAY VEHICLES 1,230,148 5,055 156,417 3,723 2,697 6,308 103,503

KY 2002 12 OFF-HIGHWAY 325,993 31 104,571 6,425 6,046 14,043 44,805

KY 2002 14 MISCELLANEOUS 9,651 50,953 209 195,827 26,941 51 4,476

2002

Total 1,754,151 57,261 537,890 265,880 69,094 580,293 290,414

KY 2009 01 FUEL COMB. ELEC. UTIL. 15,812 400 97,263 6,463 4,279 271,669 1,369

KY 2009 02 FUEL COMB. INDUSTRIAL 14,986 195 61,683 2,105 1,456 42,433 1,476

KY 2009 03 FUEL COMB. OTHER 30,045 54 5,178 7,035 6,725 10,123 9,148

KY 2009 04 CHEMICAL & ALLIED PRODUCT MFG 179 249 300 851 633 2,384 3,635

KY 2009 05 METALS PROCESSING 99,428 7 1,156 3,246 2,550 13,735 1,772

KY 2009 06 PETROLEUM & RELATED

INDUSTRIES 4,818 377 2,828 344 230 6,460 3,052

KY 2009 07 OTHER INDUSTRIAL PROCESSES 7,212 84 6,674 32,194 10,912 3,634 27,548

KY 2009 08 SOLVENT UTILIZATION 0 10 11 371 283 1 62,595

KY 2009 09 STORAGE & TRANSPORT 38 9 18 2,064 1,268 3 20,038

KY 2009 10 WASTE DISPOSAL & RECYCLING 22,388 9 1,979 7,770 6,925 733 7,725

KY 2009 11 HIGHWAY VEHICLES 963,762 5,796 101,182 2,976 1,920 759 73,942

KY 2009 12 OFF-HIGHWAY 357,800 34 94,752 5,544 5,203 9,180 38,558

KY 2009 14 MISCELLANEOUS 32,627 52,915 702 206,463 29,601 187 6,335

2009

Total 1,549,096 60,139 373,725 277,427 71,984 361,300 257,193

KY 2018 01 FUEL COMB. ELEC. UTIL. 17,144 476 64,378 6,694 4,434 222,102 1,426

KY 2018 02 FUEL COMB. INDUSTRIAL 15,692 205 64,533 2,203 1,528 43,772 1,555

KY 2018 03 FUEL COMB. OTHER 24,764 53 5,550 6,469 6,169 9,947 7,479

KY 2018 04 CHEMICAL & ALLIED PRODUCT MFG 219 317 367 1,054 781 2,884 4,384

KY 2018 05 METALS PROCESSING 114,470 9 1,508 3,898 3,065 15,800 2,343

KY 2018 06 PETROLEUM & RELATED

INDUSTRIES 5,495 434 3,244 392 262 7,426 3,394

KY 2018 07 OTHER INDUSTRIAL PROCESSES 8,303 93 7,872 35,349 12,377 4,141 31,394

KY 2018 08 SOLVENT UTILIZATION 0 12 14 464 352 1 73,525

KY 2018 09 STORAGE & TRANSPORT 44 10 21 2,408 1,481 4 21,196

KY 2018 10 WASTE DISPOSAL & RECYCLING 24,677 11 2,256 8,481 7,518 894 8,392

KY 2018 11 HIGHWAY VEHICLES 807,536 7,811 52,263 2,580 1,272 763 47,066

KY 2018 12 OFF-HIGHWAY 381,215 40 79,392 4,556 4,256 8,592 30,920

KY 2018 14 MISCELLANEOUS 33,931 55,118 729 218,725 30,626 196 7,254

2018

Total 1,433,491 64,588 282,127 293,273 74,122 316,520 240,329

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix C MACTEC, Inc. 

# 221 

# State Tier 1 Emission Totals

State Year TIER1 TIER 1 NAME CO NH3 NOX PM10 PM2.5 SO2 VOC

MS 2002 01 FUEL COMB. ELEC. UTIL. 5,303 190 43,135 1,633 1,138 67,429 648

MS 2002 02 FUEL COMB. INDUSTRIAL 22,711 28 48,699 5,011 3,638 9,746 8,024

MS 2002 03 FUEL COMB. OTHER 36,752 34 4,502 5,445 5,414 789 22,923

MS 2002 04 CHEMICAL & ALLIED PR ODUCT MFG 15,410 361 1,725 849 440 1,663 2,375

MS 2002 05 METALS PROCESSING 1,031 0 115 122 58 36 371

MS 2002 06 PETROLEUM & RELATED

INDUSTRIES 975 20 1,187 790 335 15,560 20,788

MS 2002 07 OTHER INDUSTRIAL PROCESSES 13,884 747 9,219 27,617 8,051 8,866 15,525

MS 2002 08 SOLVENT UTILIZATION 45 7 105 219 178 1 80,760

MS 2002 09 STORAGE & TRANSPORT 74 0 80 124 38 40 23,327

MS 2002 10 WASTE DISPOSAL & RECYCLING 1,414 9 89 447 324 31 886

MS 2002 11 HIGHWAY VEHICLES 864,290 3,585 111,914 2,859 2,112 4,614 87,672

MS 2002 12 OFF-HIGHWAY 236,752 23 88,787 5,010 4,690 11,315 41,081

MS 2002 14 MISCELLANEOUS 13,386 58,741 288 323,511 42,932 78 654

2002

Total 1,212,028 63,748 309,845 373,637 69,348 120,166 305,035

MS 2009 01 FUEL COMB. ELEC. UTIL. 7,116 334 47,276 5,182 4,996 76,646 564

MS 2009 02 FUEL COMB. INDUSTRIAL 24,607 30 44,095 3,728 2,787 7,388 8,007

MS 2009 03 FUEL COMB. OTHER 26,024 33 4,514 5,278 5,245 751 17,445

MS 2009 04 CHEMICAL & ALLIED PR ODUCT MFG 16,141 405 1,955 941 488 1,880 2,614

MS 2009 05 METALS PROCESSING 1,098 0 128 129 62 37 402

MS 2009 06 PETROLEUM & RELATED

INDUSTRIES 1,101 23 1,262 894 379 7,926 13,317

MS 2009 07 OTHER INDUSTRIAL PROCESSES 14,181 197 8,376 31,380 8,628 8,254 16,282

MS 2009 08 SOLVENT UTILIZATION 50 8 118 239 194 1 80,393

MS 2009 09 STORAGE & TRANSPORT 92 0 100 172 59 49 23,494

MS 2009 10 WASTE DISPOSAL & RECYCLING 1,486 10 95 473 339 32 743

MS 2009 11 HIGHWAY VEHICLES 609,972 4,035 70,743 2,275 1,508 537 52,107

MS 2009 12 OFF-HIGHWAY 257,453 25 80,567 4,270 3,985 7,191 36,197

MS 2009 14 MISCELLANEOUS 48,314 63,886 1,037 337,018 46,695 283 2,295

2009

Total 1,007,634 68,987 260,266 391,978 75,365 110,975 253,858

MS 2018 01 FUEL COMB. ELEC. UTIL. 17,348 827 21,535 7,412 7,252 15,213 1,274

MS 2018 02 FUEL COMB. INDUSTRIAL 26,082 33 46,792 4,073 3,039 5,167 8,556

MS 2018 03 FUEL COMB. OTHER 20,900 32 4,768 4,964 4,928 726 14,670

MS 2018 04 CHEMICAL & ALLIED PRODUC T MFG 20,175 475 2,337 1,132 588 2,242 3,290

MS 2018 05 METALS PROCESSING 1,357 0 167 160 79 48 461

MS 2018 06 PETROLEUM & RELATED

INDUSTRIES 1,267 26 1,294 1,010 430 8,484 14,407

MS 2018 07 OTHER INDUSTRIAL PROCESSES 16,267 216 9,996 38,492 10,492 9,657 20,301

MS 2018 08 SOLVENT UTILIZATION 60 9 141 301 244 1 98,354

MS 2018 09 STORAGE & TRANSPORT 115 0 124 210 73 62 24,537

MS 2018 10 WASTE DISPOSAL & RECYCLING 1,638 12 114 533 372 34 870

MS 2018 11 HIGHWAY VEHICLES 445,493 4,566 30,619 1,624 819 440 31,616

MS 2018 12 OFF-HIGHWAY 270,726 29 68,252 3,452 3,203 6,638 28,842

MS 2018 14 MISCELLANEOUS 50,160 70,096 1,076 352,321 47,869 294 2,377

2018

Total 871,587 76,321 187,215 415,685 79,388 49,006 249,556

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix C MACTEC, Inc. 

# 222 

# State Tier 1 Emission Totals

State Year TIER1 TIER 1 NAME CO NH3 NOX PM10 PM2.5 SO2 VOC

NC 2002 01 FUEL COMB. ELEC. UTIL. 13,885 54 151,850 22,754 16,498 477,990 988

NC 2002 02 FUEL COMB. INDUSTRIAL 23,578 301 48,590 5,596 4,334 33,395 2,540

NC 2002 03 FUEL COMB. OTHER 217,008 2,318 16,460 31,777 26,746 3,971 87,985

NC 2002 04 CHEMICAL & ALLIED PRODUCT MFG 13,952 535 859 866 538 5,736 4,313

NC 2002 05 METALS PROCESSING 5,876 60 201 564 467 1,010 2,512

NC 2002 06 PETROLEUM & RELATED

INDUSTRIES 461 0 174 104 52 283 140

NC 2002 07 OTHER INDUSTRIAL PROCESSES 8,552 480 7,380 25,328 8,924 3,426 18,025

NC 2002 08 SOLVENT UTILIZATION 130 307 229 524 484 26 151,383

NC 2002 09 STORAGE & TRANSPORT 66 46 53 639 354 1 16,120

NC 2002 10 WASTE DISPOSAL & RECYCLING 125,528 247 7,482 2,239 2,218 1,666 15,568

NC 2002 11 HIGHWAY VEHICLES 2,873,992 9,702 327,329 6,579 4,623 12,420 263,766

NC 2002 12 OFF-HIGHWAY 808,231 65 84,284 7,348 7,005 7,693 94,480

NC 2002 14 MISCELLANEOUS 35,218 158,900 757 229,909 33,291 203 1,765

2002

Total 4,126,478 173,014 645,648 334,226 105,533 547,821 659,585

NC 2009 01 FUEL COMB. ELEC. UTIL. 14,942 445 66,516 22,152 15,949 242,286 954

NC 2009 02 FUEL COMB. INDUSTRIAL 24,871 312 38,161 5,159 3,871 30,788 2,510

NC 2009 03 FUEL COMB. OTHER 158,837 2,723 18,441 25,334 19,467 4,060 49,819

NC 2009 04 CHEMICAL & ALLIED PRODUCT MFG 14,732 599 933 981 607 6,286 4,925

NC 2009 05 METALS PROCESSING 6,358 67 207 627 528 1,130 2,790

NC 2009 06 PETROLEUM & RELATED

INDUSTRIES 556 0 212 127 64 349 162

NC 2009 07 OTHER INDUSTRIAL PROCESSES 9,211 507 8,061 28,524 9,788 3,712 18,144

NC 2009 08 SOLVENT UTILIZATION 142 335 246 549 506 28 136,114

NC 2009 09 STORAGE & TRANSPORT 75 51 55 696 380 1 17,367

NC 2009 10 WASTE DISPOSAL & RECYCLING 139,518 307 8,354 2,774 2,750 1,913 17,331

NC 2009 11 HIGHWAY VEHICLES 1,991,708 11,825 201,609 5,572 3,493 1,503 168,676

NC 2009 12 OFF-HIGHWAY 887,605 72 70,997 6,055 5,760 1,892 74,056

NC 2009 14 MISCELLANEOUS 96,825 167,131 2,080 250,912 49,956 566 4,648

2009

Total 3,345,380 184,373 415,874 349,461 113,118 294,514 497,496

NC 2018 01 FUEL COMB. ELEC. UTIL. 19,870 663 61,103 35,275 28,137 120,165 1,302

NC 2018 02 FUEL COMB. INDUSTRIAL 26,873 341 40,898 5,594 4,222 32,507 2,702

NC 2018 03 FUEL COMB. OTHER 131,365 2,857 20,027 21,847 16,231 4,050 34,104

NC 2018 04 CHEMICAL & ALLIED PRODUC T MFG 18,463 702 1,105 1,175 726 7,414 6,113

NC 2018 05 METALS PROCESSING 7,576 76 255 771 657 1,335 3,516

NC 2018 06 PETROLEUM & RELATED

INDUSTRIES 712 0 272 162 82 448 207

NC 2018 07 OTHER INDUSTRIAL PROCESSES 10,675 559 9,259 34,339 11,601 4,357 20,978

NC 2018 08 SOLVENT UTILIZATION 169 375 277 588 540 31 152,979

NC 2018 09 STORAGE & TRANSPORT 91 59 67 808 430 2 19,511

NC 2018 10 WASTE DISPOSAL & RECYCLING 156,599 387 9,456 3,502 3,474 2,234 19,789

NC 2018 11 HIGHWAY VEHICLES 1,362,214 14,065 87,791 4,392 2,123 1,481 101,099

NC 2018 12 OFF-HIGHWAY 960,709 83 49,046 4,298 4,069 905 61,327

NC 2018 14 MISCELLANEOUS 111,705 177,474 2,399 273,030 54,376 655 5,333

2018

Total 2,807,022 197,643 281,955 385,780 126,667 175,583 428,960

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix C MACTEC, Inc. 

# 223 

# State Tier 1 Emission Totals

State Year TIER1 TIER 1 NAME CO NH3 NOX PM10 PM2.5 SO2 VOC

SC 2002 01 FUEL COMB. ELEC. UTIL. 6,990 142 88,241 21,400 17,154 206,399 470

SC 2002 02 FUEL COMB. INDUSTRIAL 31,771 97 38,081 5,308 3,641 44,958 1,338

SC 2002 03 FUEL COMB. OTHER 75,800 65 4,367 6,261 6,166 4,318 49,171

SC 2002 04 CHEMICAL & ALLIED PRODUCT MFG 2,526 173 25 501 318 59 8,784

SC 2002 05 METALS PROCESSING 13,833 0 450 639 408 4,160 660

SC 2002 06 PETROLEUM & RELATED

INDUSTRIES 248 0 283 120 71 170 114

SC 2002 07 OTHER INDUSTRIAL PROCESSES 9,502 1,237 15,145 15,224 6,981 12,128 16,342

SC 2002 08 SOLVENT UTILIZATION 0 1 1 78 60 0 88,878

SC 2002 09 STORAGE & TRANSPORT 10 0 4 1,025 626 0 21,009

SC 2002 10 WASTE DISPOSAL & RECYCLING 44,844 10 3,380 6,852 6,321 625 13,708

SC 2002 11 HIGHWAY VEHICLES 1,241,359 4,694 140,489 3,452 2,501 5,972 116,163

SC 2002 12 OFF-HIGHWAY 413,964 33 50,249 4,152 3,945 4,866 55,016

SC 2002 14 MISCELLANEOUS 239,836 28,975 4,678 264,959 48,898 1,281 13,655

2002

Total 2,080,683 35,426 345,395 329,971 97,090 284,936 385,308

SC 2009 01 FUEL COMB. ELEC. UTIL. 11,643 370 48,668 20,041 16,548 129,122 723

SC 2009 02 FUEL COMB. INDUSTRIAL 32,661 105 35,011 2,978 2,087 36,660 1,374

SC 2009 03 FUEL COMB. OTHER 49,914 63 4,551 5,264 5,183 4,359 25,073

SC 2009 04 CHEMICAL & ALLIED PRODUCT MFG 2,798 173 26 543 345 60 7,409

SC 2009 05 METALS PROCESSING 15,632 0 448 631 378 4,856 663

SC 2009 06 PETROLEUM & RELATED

INDUSTRIES 302 0 340 145 86 200 131

SC 2009 07 OTHER INDUSTRIAL PROCESSES 10,241 1,403 15,069 18,201 7,997 13,443 15,425

SC 2009 08 SOLVENT UTILIZATION 1 1 1 75 58 0 94,590

SC 2009 09 STORAGE & TRANSPORT 13 0 5 569 352 0 21,987

SC 2009 10 WASTE DISPOSAL & RECYCLING 70,379 11 4,215 9,526 8,977 666 15,998

SC 2009 11 HIGHWAY VEHICLES 889,957 5,523 92,499 2,862 1,855 721 72,603

SC 2009 12 OFF-HIGHWAY 448,625 36 43,235 3,471 3,294 1,701 43,061

SC 2009 14 MISCELLANEOUS 250,690 31,416 4,962 282,480 51,151 1,359 13,906

2009

Total 1,782,856 39,101 249,028 346,786 98,312 193,147 312,943

SC 2018 01 FUEL COMB. ELEC. UTIL. 14,975 625 51,751 27,640 23,794 95,377 931

SC 2018 02 FUEL COMB. INDUSTRIAL 35,532 113 36,645 3,683 2,548 38,548 1,482

SC 2018 03 FUEL COMB. OTHER 39,627 65 5,135 4,791 4,711 4,469 16,391

SC 2018 04 CHEMICAL & ALLIED PRODUCT MFG 3,296 212 32 664 423 74 9,107

SC 2018 05 METALS PROCESSING 18,853 0 585 773 476 5,920 867

SC 2018 06 PETROLEUM & RELATED

INDUSTRIES 389 0 438 186 110 258 166

SC 2018 07 OTHER INDUSTRIAL PROCESSES 12,136 1,566 17,507 20,128 8,981 15,863 18,290

SC 2018 08 SOLVENT UTILIZATION 1 1 1 93 72 0 119,154

SC 2018 09 STORAGE & TRANSPORT 16 0 6 1,380 842 0 22,739

SC 2018 10 WASTE DISPOSAL & RECYCLING 73,403 13 4,512 10,038 9,443 735 17,167

SC 2018 11 HIGHWAY VEHICLES 663,493 6,473 43,490 2,184 1,087 643 46,301

SC 2018 12 OFF-HIGHWAY 481,332 41 31,758 2,617 2,474 1,198 36,131

SC 2018 14 MISCELLANEOUS 250,637 34,345 4,961 306,342 53,367 1,359 13,896

2018

Total 1,593,690 43,455 196,820 380,519 108,327 164,444 302,623

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix C MACTEC, Inc. 

# 224 

# State Tier 1 Emission Totals

State Year TIER1 TIER 1 NAME CO NH3 NOX PM10 PM2.5 SO2 VOC

TN 2002 01 FUEL COMB. ELEC. UTIL. 7,084 204 157,307 14,640 12,166 334,151 926

TN 2002 02 FUEL COMB. INDUSTRIAL 15,257 6 44,510 8,015 6,649 74,146 2,021

TN 2002 03 FUEL COMB. OTHER 77,857 25 15,568 7,967 7,549 16,253 18,346

TN 2002 04 CHEMICAL & ALLIED PRODUCT MFG 36,920 1,518 1,772 3,246 2,201 6,516 24,047

TN 2002 05 METALS PROCESSING 41,371 14 1,182 7,620 7,030 5,818 6,898

TN 2002 06 PETROLEUM & RELATED

INDUSTRIES 543 0 331 314 243 383 1,850

TN 2002 07 OTHER INDUSTRIAL PROCESSES 9,420 44 11,794 30,484 12,867 5,845 27,336

TN 2002 08 SOLVENT UTILIZATION 275 1 5,066 2,103 1,818 58 110,872

TN 2002 09 STORAGE & TRANSPORT 22 24 105 1,249 736 134 21,962

TN 2002 10 WASTE DISPOSAL & RECYCLING 22,143 31 1,839 7,068 6,469 349 15,505

TN 2002 11 HIGHWAY VEHICLES 1,917,842 6,625 238,577 5,371 3,949 9,226 179,807

TN 2002 12 OFF-HIGHWAY 505,163 43 96,827 6,819 6,458 10,441 66,450

TN 2002 14 MISCELLANEOUS 5,003 34,292 100 179,440 24,708 25 1,978

2002

Total 2,638,901 42,825 574,980 274,337 92,841 463,345 477,997

TN 2009 01 FUEL COMB. ELEC. UTIL. 7,214 227 66,405 15,608 13,092 255,410 932

TN 2009 02 FUEL COMB. INDUSTRIAL 15,536 6 37,046 7,157 5,973 63,076 1,773

TN 2009 03 FUEL COMB. OTHER 61,442 27 14,792 7,134 6,786 16,955 12,781

TN 2009 04 CHEMICAL & ALLIED PRODUCT MFG 35,440 1,719 1,958 3,369 2,271 1,949 15,492

TN 2009 05 METALS PROCESSING 45,183 15 1,245 7,337 6,823 6,537 7,671

TN 2009 06 PETROLEUM & RELATED

INDUSTRIES 572 0 328 355 276 263 1,401

TN 2009 07 OTHER INDUSTRIAL PROCESSES 9,911 62 12,635 32,599 13,687 6,240 28,338

TN 2009 08 SOLVENT UTILIZATION 309 1 5,983 2,431 2,095 65 112,264

TN 2009 09 STORAGE & TRANSPORT 26 31 12 1,218 733 42 23,686

TN 2009 10 WASTE DISPOSAL & RECYCLING 23,810 35 1,993 7,618 6,968 393 14,922

TN 2009 11 HIGHWAY VEHICLES 1,338,016 7,782 151,912 4,206 2,751 1,076 115,181

TN 2009 12 OFF-HIGHWAY 554,121 48 86,641 5,877 5,557 5,651 55,358

TN 2009 14 MISCELLANEOUS 17,921 35,200 379 192,464 26,830 102 2,814

2009

Total 2,109,500 45,152 381,331 287,371 93,842 357,760 392,612

TN 2018 01 FUEL COMB. ELEC. UTIL. 7,723 241 31,715 15,941 13,387 112,672 976

TN 2018 02 FUEL COMB. INDUSTRIAL 16,702 7 38,028 7,648 6,408 47,982 1,905

TN 2018 03 FUEL COMB. OTHER 54,486 30 15,502 6,757 6,412 18,091 10,269

TN 2018 04 CHEMICAL & ALLIED PRODUCT MFG 45,455 2,053 2,424 4,263 2,888 6,563 19,950

TN 2018 05 METALS PROCESSING 52,834 17 1,589 9,579 8,953 7,790 9,950

TN 2018 06 PETROLEUM & RELATED

INDUSTRIES 665 0 378 414 324 309 1,598

TN 2018 07 OTHER INDUSTRIAL PROCESSES 10,946 88 14,157 38,196 16,242 7,286 35,126

TN 2018 08 SOLVENT UTILIZATION 380 1 7,675 3,154 2,717 79 140,760

TN 2018 09 STORAGE & TRANSPORT 33 41 14 1,571 939 49 25,491

TN 2018 10 WASTE DISPOSAL & RECYCLING 26,712 42 2,326 8,562 7,828 468 17,530

TN 2018 11 HIGHWAY VEHICLES 976,634 9,021 69,385 3,092 1,544 948 67,324

TN 2018 12 OFF-HIGHWAY 593,100 55 70,226 4,672 4,403 5,207 45,084

TN 2018 14 MISCELLANEOUS 19,210 36,213 408 209,058 28,209 111 3,293

2018

Total 1,804,879 47,809 253,828 312,906 100,255 207,555 379,257

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix C MACTEC, Inc. 

# 225 

# State Tier 1 Emission Totals

State Year TIER1 TIER 1 NAME CO NH3 NOX PM10 PM2.5 SO2 VOC

VA 2002 01 FUEL COMB. ELEC. UTIL. 6,892 127 86,886 3,960 2,606 241,204 754

VA 2002 02 FUEL COMB. INDUSTRIAL 64,398 100 75,831 18,480 8,453 137,451 5,332

VA 2002 03 FUEL COMB. OTHER 98,788 13 15,648 11,572 11,236 5,508 54,496

VA 2002 04 CHEMICAL & ALLIED PRODUC T MFG 321 2,158 8,062 449 393 2,126 1,530

VA 2002 05 METALS PROCESSING 3,580 0 937 1,575 1,349 5,251 513

VA 2002 06 PETROLEUM & RELATED

INDUSTRIES 23,384 0 182 255 153 170 501

VA 2002 07 OTHER INDUSTRIAL PROCESSES 12,002 726 9,279 33,409 9,795 17,702 13,086

VA 2002 08 SOLVENT UTILIZATION 0 4 0 225 210 2 111,511

VA 2002 09 STORAGE & TRANSPORT 16 7 11 745 505 0 26,121

VA 2002 10 WASTE DISPOSAL & RECYCLING 16,566 109 1,866 3,152 1,277 1,581 4,065

VA 2002 11 HIGHWAY VEHICLES 2,163,259 7,852 222,374 4,549 3,102 8,294 159,790

VA 2002 12 OFF-HIGHWAY 660,105 48 63,219 8,728 8,288 8,663 74,866

VA 2002 14 MISCELLANEOUS 16,238 43,961 350 182,486 22,086 92 848

2002

Total 3,065,551 55,105 484,646 269,585 69,453 428,046 453,413

VA 2009 01 FUEL COMB. ELEC. UTIL. 12,535 694 64,358 5,606 4,165 174,777 788

VA 2009 02 FUEL COMB. INDUSTRIAL 67,422 105 67,263 18,346 8,345 131,459 5,483

VA 2009 03 FUEL COMB. OTHER 66,016 10 15,920 10,059 9,741 5,118 28,062

VA 2009 04 CHEMICAL & ALLIED PRODUC T MFG 286 2,082 7,790 477 413 1,996 1,419

VA 2009 05 METALS PROCESSING 3,397 0 827 1,563 1,332 4,813 390

VA 2009 06 PETROLEUM & RELATED

INDUSTRIES 26,288 0 197 275 169 187 557

VA 2009 07 OTHER INDUSTRIAL PROCESSES 12,471 733 9,425 33,961 9,984 18,643 13,394

VA 2009 08 SOLVENT UTILIZATION 0 5 0 248 231 3 110,127

VA 2009 09 STORAGE & TRANSPORT 17 7 12 797 544 0 26,456

VA 2009 10 WASTE DISPOSAL & RECYCLING 20,109 119 2,174 3,823 1,515 1,805 4,789

VA 2009 11 HIGHWAY VEHICLES 1,453,946 9,086 134,232 3,747 2,241 1,079 96,770

VA 2009 12 OFF-HIGHWAY 726,815 53 54,993 7,510 7,136 1,707 57,009

VA 2009 14 MISCELLANEOUS 21,582 46,719 464 198,040 23,990 124 1,077

2009

Total 2,410,884 59,612 357,655 284,451 69,806 341,710 346,321

VA 2018 01 FUEL COMB. ELEC. UTIL. 18,850 606 64,344 12,551 10,773 98,988 980

VA 2018 02 FUEL COMB. INDUSTRIAL 72,065 114 70,132 19,247 8,904 134,790 5,861

VA 2018 03 FUEL COMB. OTHER 53,171 14 17,852 9,427 9,086 5,230 18,603

VA 2018 04 CHEMICAL & ALLIED PRODUC T MFG 338 2,462 9,211 579 502 1,297 1,708

VA 2018 05 METALS PROCESSING 4,034 0 1,017 1,861 1,592 5,374 469

VA 2018 06 PETROLEUM & RELATED

INDUSTRIES 30,284 0 228 315 194 217 642

VA 2018 07 OTHER INDUSTRIAL PROCESSES 14,029 877 10,836 37,553 11,276 18,088 15,636

VA 2018 08 SOLVENT UTILIZATION 0 6 0 314 293 3 127,953

VA 2018 09 STORAGE & TRANSPORT 21 8 15 949 648 0 27,357

VA 2018 10 WASTE DISPOSAL & RECYCLING 24,293 141 2,595 4,694 1,828 2,170 5,821

VA 2018 11 HIGHWAY VEHICLES 1,075,104 10,624 63,342 3,212 1,543 1,043 61,964

VA 2018 12 OFF-HIGHWAY 797,683 61 40,393 6,208 5,891 507 49,052

VA 2018 14 MISCELLANEOUS 27,223 50,279 584 218,141 26,225 158 1,322

2018

Total 2,117,096 65,192 280,549 315,051 78,754 267,867 317,368

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix C MACTEC, Inc. 

# 226 

# State Tier 1 Emission Totals

State Year TIER1 TIER 1 NAME CO NH3 NOX PM10 PM2.5 SO2 VOC

WV 2002 01 FUEL COMB. ELEC. UTIL. 10,341 121 230,977 4,573 2,210 516,084 1,180

WV 2002 02 FUEL COMB. INDUSTRIAL 8,685 97 33,825 1,583 1,332 37,111 1,097

WV 2002 03 FUEL COMB. OTHER 29,480 13 15,220 3,814 3,683 3,990 9,275

WV 2002 04 CHEMICAL & ALLIED PR ODUCT MFG 50,835 80 1,627 950 831 9,052 5,755

WV 2002 05 METALS PROCESSING 28,837 143 1,570 8,749 7,515 5,619 1,393

WV 2002 06 PETROLEUM & RELATED INDUSTRIES 1 0 1,086 475 475 7,550 2,163

WV 2002 07 OTHER INDUSTRIAL PROCESSES 2,003 56 5,347 18,751 5,567 2,316 1,803

WV 2002 08 SOLVENT UTILIZATION 15 0 18 49 44 0 35,989

WV 2002 09 STORAGE & TRANSPORT 15 0 3 1,952 947 0 12,432

WV 2002 10 WASTE DISPOSAL & RECYCLING 9,395 8 599 4,153 3,731 100 5,098

WV 2002 11 HIGHWAY VEHICLES 533,471 1,908 58,999 1,381 995 2,464 42,174

WV 2002 12 OFF-HIGHWAY 133,113 9 33,239 1,850 1,728 2,112 18,566

WV 2002 14 MISCELLANEOUS 6,897 9,928 149 93,030 10,799 40 349

2002

Total 813,089 12,364 382,659 141,310 39,857 586,436 137,275

WV 2009 01 FUEL COMB. ELEC. UTIL. 11,493 330 85,476 5,657 2,940 268,952 1,361

WV 2009 02 FUEL COMB. INDUSTRIAL 9,529 104 27,109 1,432 1,243 36,964 979

WV 2009 03 FUEL COMB. OTHER 21,558 13 14,229 3,351 3,216 4,047 6,824

WV 2009 04 CHEMICAL & ALLIED PR ODUCT MFG 58,271 82 1,804 981 858 10,102 5,426

WV 2009 05 METALS PROCESSING 24,501 116 1,494 2,016 1,507 5,608 831

WV 2009 06 PETROLEUM & RELATED INDUSTRIES 1 0 1,221 535 535 8,495 2,172

WV 2009 07 OTHER INDUSTRIAL PROCESSES 2,288 59 4,995 19,240 5,910 2,570 2,064

WV 2009 08 SOLVENT UTILIZATION 17 0 20 52 47 0 32,199

WV 2009 09 STORAGE & TRANSPORT 17 0 3 1,756 695 0 12,997

WV 2009 10 WASTE DISPOSAL & RECYCLING 9,131 8 583 4,036 3,618 97 4,806

WV 2009 11 HIGHWAY VEHICLES 365,549 2,148 35,635 1,068 684 279 24,843

WV 2009 12 OFF-HIGHWAY 152,862 11 30,133 1,640 1,528 359 18,069

WV 2009 14 MISCELLANEOUS 4,116 10,574 89 93,957 11,002 23 219

2009

Total 659,332 13,446 202,791 135,720 33,782 337,495 112,790

WV 2018 01 FUEL COMB. ELEC. UTIL. 12,397 143 51,474 5,784 3,116 106,199 1,387

WV 2018 02 FUEL COMB. INDUSTRIAL 10,174 111 28,764 1,505 1,308 38,571 1,048

WV 2018 03 FUEL COMB. OTHER 18,891 16 17,254 3,160 3,024 4,065 6,270

WV 2018 04 CHEMICAL & ALLIED PRODUC T MFG 70,252 99 2,183 1,181 1,034 12,196 6,560

WV 2018 05 METALS PROCESSING 28,563 148 1,929 2,491 1,887 6,735 1,087

WV 2018 06 PETROLEUM & RELATED INDUSTRIES 1 0 1,407 616 616 9,786 2,338

WV 2018 07 OTHER INDUSTRIAL PROCESSES 2,756 68 5,949 21,363 6,809 3,101 2,561

WV 2018 08 SOLVENT UTILIZATION 20 0 24 61 55 0 37,886

WV 2018 09 STORAGE & TRANSPORT 19 0 4 2,080 824 0 13,394

WV 2018 10 WASTE DISPOSAL & RECYCLING 9,237 10 592 4,116 3,674 98 5,153

WV 2018 11 HIGHWAY VEHICLES 274,804 2,497 17,247 819 405 253 16,121

WV 2018 12 OFF-HIGHWAY 167,424 13 25,710 1,292 1,198 56 14,086

WV 2018 14 MISCELLANEOUS 5,175 11,453 112 99,667 11,803 29 268

2018

Total 599,712 14,557 152,647 144,134 35,752 181,088 108,159

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix C MACTEC, Inc. 

# 227 

# State Tier 1 Emission Totals

CO NH3 NOX PM10 PM2.5 SO2 VOC

VISTAS 2002 Total 30,073,168 665,818 5,429,845 3,895, 998 1,075,343 4,879,941 5,178,836



# VISTAS 2009 Total 25,397,398 721,736 3,790,044 4,160, 870 1,123,548 3,465,859 4,187,921



# VISTAS 2018 Total 22,645,302 792,678 2,722,636 4,548, 634 1,194,728 2,169,725 3,910,170

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix D MACTEC, Inc. 

# 228 

# APPENDIX D:

VISTAS TIER 1 EMISSION TOTALS

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix D MACTEC, Inc. 

# 229 

# VISTAS Tier 1 Emission Totals

Year TIER1 TIER1NAME CO NH3 NOX PM10-

PRI PM25-

PRI SO2 VOC

2002 01 FUEL COMB. ELEC. UTIL. 141,217 1,799 1,523,445 113,917 79,269 3,743,723 12,515

2002 02 FUEL COMB. INDUSTRIAL 371,932 1,204 499,943 85,357 59,735 550,866 32,333

2002 03 FUEL COMB. OTHER 759,534 2,810 122,062 99,532 91,805 114,852 354,375

2002 04 CHEMICAL & ALLIED PRODUCT MF G 131,993 7,093 20,896 11,114 7,982 77,450 63,748

2002 05 METALS PROCESSING 223,705 601 11,801 32,367 27,778 49,143 17,306

2002 06 PETROLEUM & RELATED INDUSTRIES 44,633 355 7,204 2,887 1,863 53,392 33,374

2002 07 OTHER INDUSTRIAL PROCESSES 156,077 7,520 114,474 267,980 97,013 86,736 196,831

2002 08 SOLVENT UTILIZATION 687 331 5,677 3,805 3,284 90 1,288,990

2002 09 STORAGE & TRANSPORT 610 85 1,069 10,968 6,100 230 261,959

2002 10 WASTE DISPOSAL & RECYCLING 546,331 801 28,738 80,336 73,673 6,418 99,497

2002 11 HIGHWAY VEHICLES 19,432,305 73,670 2,187,683 50,338 35,813 89,296 1,890,798

2002 12 OFF-HIGHWAY 6,209,596 477 865,130 72,019 68,302 96,336 813,788

2002 14 MISCELLANEOUS 2,054,548 569,073 41,724 3,065,377 522,726 11,407 113,321

2002

Total 30,073,168 665,818 5,429,845 3,895,998 1,075,343 4,879,941 5,178,836

2009 01 FUEL COMB. ELEC. UTIL. 190,535 5,474 789,299 125,750 91,587 2,497,423 14,208

2009 02 FUEL COMB. INDUSTRIAL 391,422 1,305 445,967 74,588 51,491 514,636 32,431

2009 03 FUEL COMB. OTHER 544,289 3,198 123,297 85,410 77,042 112,323 207,146

2009 04 CHEMICAL & ALLIED PRODUCT MF G 140,910 7,611 22,031 11,742 8,394 76,021 54,168

2009 05 METALS PROCESSING 236,473 705 11,763 25,130 21,288 54,337 17,954

2009 06 PETROLEUM & RELATED INDUSTRIES 48,118 399 7,863 3,282 2,124 46,975 25,028

2009 07 OTHER INDUSTRIAL PROCESSES 166,088 7,545 117,625 298,719 111,218 90,420 202,567

2009 08 SOLVENT UTILIZATION 771 360 6,662 4,274 3,679 100 1,256,884

2009 09 STORAGE & TRANSPORT 702 98 1,087 10,729 5,743 160 275,462

2009 10 WASTE DISPOSAL & RECYCLING 770,459 869 36,697 105,449 97,841 7,287 113,473

2009 11 HIGHWAY VEHICLES 13,864,869 87,027 1,414,834 41,861 26,498 10,962 1,217,185

2009 12 OFF-HIGHWAY 6,827,857 530 767,707 61,528 58,279 42,845 649,786

2009 14 MISCELLANEOUS 2,214,906 606,617 45,212 3,312,407 568,364 12,370 121,629

2009

Total 25,397,398 721,736 3,790,044 4,160,870 1,123,548 3,465,859 4,187,921

2018 01 FUEL COMB. ELEC. UTIL. 262,414 9,306 568,158 152,642 118,959 1,169,110 17,090

2018 02 FUEL COMB. INDUSTRIAL 416,721 1,383 470,326 80,011 55,648 513,072 34,720

2018 03 FUEL COMB. OTHER 453,482 3,358 136,431 78,032 69,854 116,672 149,363

2018 04 CHEMICAL & ALLIED PRODUCT MF G 173,857 9,023 26,564 14,454 10,360 94,010 67,414

2018 05 METALS PROCESSING 279,850 926 14,871 31,221 26,572 66,150 23,089

2018 06 PETROLEUM & RELATED INDUSTRIES 53,392 460 8,891 3,845 2,490 43,055 27,283

2018 07 OTHER INDUSTRIAL PROCESSES 189,922 8,793 136,722 348,119 130,778 100,824 237,601

2018 08 SOLVENT UTILIZATION 936 404 8,480 5,354 4,601 119 1,515,005

2018 09 STORAGE & TRANSPORT 855 119 1,258 13,540 7,283 192 290,267

2018 10 WASTE DISPOSAL & RECYCLING 821,737 1,068 40,324 114,690 105,745 8,544 125,406

2018 11 HIGHWAY VEHICLES 10,312,627 103,394 663,796 33,426 16,403 10,281 752,732

2018 12 OFF-HIGHWAY 7,438,312 612 601,040 48,648 45,927 35,166 546,062

2018 14 MISCELLANEOUS 2,241,196 653,831 45,776 3,624,653 600,107 12,532 124,137

2018

Total 22,645,302 792,678 2,722,636 4,548,634 1,194,728 2,169,725 3,910,170

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix E MACTEC, Inc. 

# 230 

# APPENDIX E:

AIRCRAFT PM EXCERPT FR OM 2001 TUCSON REPORT

# Final Report

EMISSIONS INVENTORIES FOR

THE TUCSON AIR PLANNING AREA

VOLUME I. STUDY DESCRIPTION AND RESULTS

Prepared for

Pima Association of Governments

177 N. Church Avenue, Suite 405

Tucson, AZ 85701

Prepared by

Marianne Causley

Rumla, Inc.

3243 Gloria Terrace

Lafayette, CA 94549

Daniel Meszler

Energy and Environmental Analysis, Inc.

1655 North Fort Myer Drive

Arlington, VA 22209

Russell Jones

Stratus Consulting, Inc.

P.O. Box 4059

Boulder, CO 80306-4059

Steven Reynolds

Envair

12 Palm Avenue

San Rafael, CA 94901

November 2001

# Emissions Inventories for the Tucson Air Planning Area

Tucson Aircraft PM.doc 

# i Final Report —November 2001 

# ACKNOWLEDGEMENTS

The authors extend their appreciation to the many individuals that contributed to this study.

Particular thanks go to the staff of the Pima Association of Governments. Darcy Anderson was

instrumental in providing definition at the outset of the study. Lee Comrie and Natalie Barnes

provided considerable assistance with the emissions surveys, made many thoughtful suggestions

and contributions throughout the study, and provided helpful comments on the draft final report.

Kwame Agyare, Wayne Byrd and Bill Maxwell of the Pima County Department of

Environmental Quality offered valuable assistance in providing socioeconomic and PDEQ permit

data and in sharing their knowledge of emissions sources in the Tucson Air Planning Area. Dan

Catlin of the Arizona Department of Environmental Quality provided insightful comments

during the course of the study and reviewed the draft final report.

Many individuals in the Tucson area participated in the annual and day-specific emissions

surveys conducted as part of this study. The information they provided is sincerely appreciated.

We also wish to acknowledge Patricia El-Gasseir and Helen Fugate of Rumla, Inc. for their

dedicated efforts in building the facilities database.

# Emissions Inventories for the Tucson Air Planning Area

Tucson Aircraft PM.doc 

# iii Final Report —November 2001 

# TABLE OF CONTENTS

ACKNOWLEDGEMENTS ...................................................................................... i

LIST OF TABLES .................................................................................................... viii

LIST OF FIGURES................................................................................................... xiii

ABBREVIATIONS AND ACRONYMS.................................................................. xiv

EXECUTIVE SUMMARY....................................................................................... ES-1

1 BACKGROUND................................................................................................... 1-1

1.1 Current Air Quality Status of the Tucson Area....................................... 1-1

1.1.1 Ozone ................................................................................................ 1-1

1.1.2 Carbon Monoxide.............................................................................. 1-3

1.1.3 Particulate Matter .............................................................................. 1-3

1.2 Overview of the Emissions Inventories................................................... 1-4

1.3 Emissions Support for Photochemical Modeling in Tucson................... 1-6

1.4 Organization of This Report.................................................................... 1-7

2 POINT SOURCES ................................................................................................ 2-1

2.1 Identification of Sources ......................................................................... 2-1

2.2 Data Collection........................................................................................ 2-2

2.3 Data Entry ............................................................................................... 2-4

2.4 Calculation Methodologies ..................................................................... 2-5

2.4.1 Emissions Based on 2000 Actual Data ............................................. 2-6

2.4.2 Emissions Based on Adjustment of 1999 Data ................................. 2-7

2.4.3 Emissions Based on General Activity Data....................................... 2-7

2.4.4 Emissions Based on Evaporative Processes...................................... 2-8

2.5 Data Quality and Completeness .............................................................. 2-9

2.6 Future Year Estimations.......................................................................... 2-11

2.7 Point Source Emissions Summary .......................................................... 2-12

2.8 Temporal Activity Data........................................................................... 2-13

2.8.1 Point Source TAF Comparison ......................................................... 2-15

2.8.2 Point and Area TAF Comparison...................................................... 2-16

3 STATIONARY AREA SOURCES ...................................................................... 3-1

3.1 Architectural Coating .................................................................. 3-4

3.1.1 Methodology....................................................................................... 3-4

3.1.2 Calculations ........................................................................................ 3-5

3.2 Asphalt Paving.......................................................................................... 3-6

3.2.1 Methodology....................................................................................... 3-6

3.2.2 Calculations ........................................................................................ 3-7

# Emissions Inventories for the Tucson Air Planning Area

Tucson Aircraft PM.doc 

# iv Final Report —November 2001 

# TABLE OF CONTENTS (Continued)

3.3 Automobile Refinishing ........................................................................... 3-7

3.3.1 Methodology....................................................................................... 3-7

3.3.2 Calculations ........................................................................................ 3-8

3.4 Commercial Bakeries ............................................................................... 3-9

3.4.1 Methodology....................................................................................... 3-9

3.4.2 Calculations ........................................................................................ 3-9

3.5 Consumer Solvent Usage ......................................................................... 3-10

3.5.1 Methodology....................................................................................... 3-10

3.5.2 Calculations ........................................................................................ 3-10

3.6 Dry Cleaning............................................................................................. 3-11

3.6.1 Methodology....................................................................................... 3-11

3.6.2 Calculations ........................................................................................ 3-12

3.7 Forest Fires and Prescribed Burnings....................................................... 3-13

3.7.1 Methodology....................................................................................... 3-13

3.7.2 Calculations ........................................................................................ 3-13

3.8 Gasoline Distribution ............................................................................... 3-15

3.8.1 Methodology....................................................................................... 3-15

3.8.2 Calculations ........................................................................................ 3-17

3.9 Graphic Arts ............................................................................................. 3-18

3.9.1 Methodology....................................................................................... 3-18

3.9.2 Calculations ........................................................................................ 3-18

3.10 Industrial Surface Coating........................................................................ 3-18

3.10.1 Methodology....................................................................................... 3-19

3.10.2 Calculations ........................................................................................ 3-19

3.11 Misc. Residential/Commercial Fuel Combustion .................................... 3-20

3.11.1 Methodology....................................................................................... 3-20

3.11.2 Calculations ........................................................................................ 3-21

3.12 Pesticide Application................................................................................ 3-23

3.12.1 Methodology....................................................................................... 3-24

3.12.2 Calculations ........................................................................................ 3-25

3.13 Residential Wood Combustion................................................................. 3-25

3.13.1 Methodology....................................................................................... 3-26

3.13.2 Calculations ........................................................................................ 3-26

# Emissions Inventories for the Tucson Air Planning Area

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# v Final Report —November 2001 

# TABLE OF CONTENTS (Continued)

3.14 Solvent Cleaning ...................................................................................... 3-28

3.14.1 Methodology....................................................................................... 3-28

3.14.2 Calculations ........................................................................................ 3-29

3.15 Structure and Vehicle Fires ..................................................................... 3-29

3.15.1 Methodology....................................................................................... 3-30

3.15.2 Calculations ........................................................................................ 3-30

3.16 Traffic Markings....................................................................................... 3-32

3.16.1 Methodology....................................................................................... 3-32

3.16.2 Calculations ........................................................................................ 3-33

3.17 Area Source Annual Emissions Summaries............................................. 3-33

3.18 Day-specific Area Source Emissions Summaries..................................... 3-41

4 NONROAD MOBILE SOURCES........................................................................ 4-1

4.1 Introduction ............................................................................................. 4-1

4.2 General Use Nonroad Equipment............................................................ 4-4

4.2.1 Basic Inventory Methodology ........................................................... 4-6

4.2.2 NONROAD Model Inputs................................................................. 4-11

4.2.3 Emission Estimates for Calendar Year 2000..................................... 4-14

4.2.4 Emissions Estimates for Tuesday August 22, 2000 .......................... 4-17

4.2.5 Emissions Estimates for Sunday September 10, 2000 ...................... 4-21

4.2.6 Emissions Estimates for Saturday April 14, 2001............................. 4-21

4.2.7 Emissions Estimates for Tuesday April 24, 2001 ............................. 4-22

4.2.8 Emissions Estimates for Calendar Year 2005 ................................... 4-24

4.2.9 Emissions Estimates for Calendar Year 2010 ................................... 4-25

4.2.10 Temporal Allocation Factors for General Use Nonroad Equipment. 4-27

4.3 Aircraft Operations........................................................................................ 4-28

4.3.1 Commercial Air Carrier Emission Estimates for Calendar Year 2000 4-30

4.3.2 Commercial Air Carrier APU Emission Estimates for

Calendar Year 2000.................................................................. 4-44

4.3.3 Other Aircraft Emissions for Calendar Year 2000............................ 4-45

4.3.4 Other Potential Aircraft Emissions Sources Not Currently Considered 4-64

4.3.5 Aircraft Emissions Estimates for Tuesday August 22, 2000............. 4-68

4.3.6 Aircraft Emissions Estimates for Sunday September 10, 2000......... 4-69

4.3.7 Aircraft Emissions Estimates for Saturday April 14, 2001 ............... 4-70

4.3.8 Aircraft Emissions Estimates for Tuesday April 24, 2001................ 4-70

4.3.9 Aircraft Emissions Estimates for Calendar Year 2005 ..................... 4-77

4.3.10 Aircraft Emissions Estimates for Calendar Year 2010 ..................... 4-83

4.3.11 Day-Specific and Forecast Aircraft Emission Estimates for TIA ..... 4-88

4.3.12 Temporal Allocation Factors for Aircraft Emissions........................ 4-88

# Emissions Inventories for the Tucson Air Planning Area

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# vi Final Report —November 2001 

# TABLE OF CONTENTS (Continued)

4.4 Aircraft Ground Support Equipment 4-88

4.4.1 GSE Emissions Estimates for Calendar Year 2000 .......................... 4-94

4.4.2 GSE Emissions Estimates for Tuesday August 22, 2000.................. 4-102

4.4.3 GSE Emissions Estimates for Sunday September 10, 2000.............. 4-104

4.4.4 GSE Emissions Estimates for Saturday April 14, 2001 .................... 4-104

4.4.5 GSE Emissions Estimates for Tuesday April 24, 2001..................... 4-108

4.4.6 GSE Emissions Estimates for Calendar Year 2005 .......................... 4-108

4.4.7 GSE Emissions Estimates for Calendar Year 2010 .......................... 4-108

4.4.8 Temporal Allocation Factors for GSE Emissions ............................. 4-108

4.5 Commercial Marine Operations .................................................................... 4-113

4.6 Locomotive Operations ................................................................................. 4-113

4.6.1 Locomotive Emission Estimates for Calendar Year 2000 ................ 4-114

4.6.2 Day-Specific Locomotive Emission Estimates for

Calendar Year 2000................................................................. 4-124

4.6.3 Day-Specific Locomotive Emission Estimates for

Calendar Year 2001.................................................................. 4-125

4.6.4 Locomotive Emission Estimates for

Calendar Years 2005 and 2010 ................................................ 4-125

4.6.5 Temporal Allocation Factors for Locomotive Emissions ................. 4-125

5 MODEL INVENTORY PREPARATION ........................................................... 5-1

5.1 Overview ....................................................................................................... 5-1

5.1.1 Spatial Resolution of Emissions........................................................ 5-2

5.1.2 Temporal Resolution of Emissions ................................................... 5-2

5.1.3 Chemical Resolution of Emissions ................................................... 5-3

5.2 Inventory Preparation .................................................................................... 5-3

5.2.1 Emission Data ................................................................................... 5-6

5.2.2 Spatial Allocation.............................................................................. 5-6

5.2.3 Temporal Allocation ......................................................................... 5-11

5.2.4 Chemical Speciation.......................................................................... 5-11

5.3 Emission Processing System......................................................................... 5-12

5.3.1 Output Formats.................................................................................. 5-12

5.4 Summary of Modeling Inventories................................................................ 5-14

6 DATA QUALITY REVIEW................................................................................ 6-1

6.1 Point Sources................................................................................................. 6-1

6.2 Area Sources ................................................................................................. 6-3

6.3 Nonroad Mobile Sources............................................................................... 6-4

6.4 Photochemical Air Quality Model Input Files .............................................. 6-5

6.5 External Review ............................................................................................ 6-6

6.6 Overall Comments on the Inventories........................................................... 6-9

7 REFERENCES..................................................................................................... 7-1

# Emissions Inventories for the Tucson Air Planning Area

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# vii Final Report —November 2001 

# TABLE OF CONTENTS (Concluded)

APPENDIX 2A. LIST OF PAG MAJOR AND MINOR FACILITIES

CONTACTED DURING SURVEY ACTIVITIES .......................... 2A-1

APPENDIX 2B. REVISED ANNUAL SURVEY FORM FOR

MAJOR FACILITIES ....................................................................... 2B-1

APPENDIX 2C. REVISED ANNUAL SURVEY FORMS FOR

MINOR FACILITIES........................................................................ 2C-1

APPENDIX 2D. PAG 2000 TOTAL EMISSIONS BY FACILITY ................... 2D-1

APPENDIX 3A. ASC SPATIAL ALLOCATION SURROGATE ASSIGNMENT 3A-1

APPENDIX 4A. NONROAD MOBILE SOURCE EMISSIONS BY SCC........ 4A-1

APPENDIX 4B. NONROAD MOBILE SOURCE TEMPORAL

ALLOCATION FACTORS .............................................................. 4B-1

APPENDIX 5A. NATIONAL EMISSION INVENTORY (NEI)

RECORD FORMATS....................................................................... 5A-1

APPENDIX 5B. SPATIAL ALLOCATION OF EMISSIONS USING GIS....... 5B-1

APPENDIX 5C. EDBsys EMISSION OUTPUT FORMATS............................. 5C-1

# Emissions Inventories for the Tucson Air Planning Area

Tucson Aircraft PM.doc 

# viii Final Report —November 2001 

# LIST OF TABLES

Table 1-1. Inventories for the Tucson Air Planning Area ........................................... 1-2

Table 2-1. PDEQ Permitted Facilities Flagged as a Major Point Source.................... 2-2

Table 2-2. PAG Survey Response Rates ..................................................................... 2-4

Table 2-3. NEI Record Elements for the PAG Inventory............................................ 2-5

Table 2-4. 2000 Emission Estimates Adjustments from Surveys ............................... 2-7

Table 2-5. Resolution of Survey Data Issues and Possible Inventory Effect .............. 2-9

Table 2-6. Ranges of EGAS Growth Factors from 2000 Baseline.............................. 2-12

Table 2-7. Annual Emissions Estimates for Major and Minor Point Sources ............ 2-12

Table 2-8. Day-specific Criteria Pollutant Totals (tons per day) ................................ 2-13

Table 2-9. Survey Responses for Temporal Activity Profile Information .................. 2-14

Table 3-1. TAPA Inventory Area Source Categories ................................................. 3-1

Table 3-2. Socioeconomic Parameters Applied to 2000 and Projected Year

Emission Estimations........................................................................... 3-3

Table 3-3. Projection Factors for the 2005 and 2010 Emission Estimates.................. 3-3

Table 3-4. Allocation Adjustment Factors .................................................................. 3-3

Table 3-5. Architectural Coatings Gallons Per Capita Calculations........................... 3-5

Table 3-6. TAPA Annual Architectural Coating VOC Emission Estimates............... 3-6

Table 3-7. Growth Factors for the Automobile Refinishing Employment

in the Tucson Area ............................................................................... 3-8

Table 3-8. TAPA Annual Automobile Refinishing VOC Emissions.......................... 3-8

Table 3-9. Commercial Bakery Process Emission Factors ......................................... 3-10

Table 3-10. TAPA Bakeries VOC Emission Estimates .............................................. 3-10

Table 3-11. TAPA Consumer Product Per Capita Factors and

Emission Estimates (tons) ................................................................... 3-11

Table 3-12. Dry Cleaning Telephone Survey Responses ............................................ 3-12

Table 3-13. Pima County Acres Burned During 2000 ................................................ 3-13

Table 3-14. Emission Factors for Estimation of Forest Fire and Prescribed Burnings 3-14

Table 3-15. TAPA 2000 Emissions from Forest Fires and Prescribed Burnings (tons) 3-14

Table 3-16. TAPA 2005 and 2010 Emissions from Forest Fires and Prescribed

Burnings (tons/year) ............................................................................. 3-15

Table 3-17. Year 2000 Gasoline Tax Sales (gallons) ................................................. 3-16

Table 3-18. TAPA VOC Emissions from Gasoline Marketing Activities (tons) ....... 3-17

Table 3-19. TAPA VOC Emissions from Graphic Arts (tons) .................................. 3-18

Table 3-20. ZIP Codes Included for Dun & Bradstreet Extraction ............................. 3-19

Table 3-21. TAPA VOC Emission Estimates for Industrial Surface Coating (tons) . 3-20

Table 3-22. Natural Gas and LPG Emission Factors ................................................. 3-21

Table 3-23. 2000 Natural Gas and LPG Sales for the Tucson Area............................ 3-22

Table 3-24. TAPA 2000 Emissions from Miscellaneous Combustion (tons/year) .... 3-22

Table 3-25. TAPA 2005 Emissions from Miscellaneous Combustion (tons/year) .... 3-23

Table 3-26. TAPA 2010 Emissions from Miscellaneous Combustion (tons/year)..... 3-23

# Emissions Inventories for the Tucson Air Planning Area

Tucson Aircraft PM.doc 

# ix Final Report —November 2001 

# LIST OF TABLES (Continued)

Table 3-27. Identified Survey Contacts and Responses for the Source

Category Pesticide Application........................................................... 3-24

Table 3-28. Growth Factors for the Dwelling Units in the Tucson Area.................... 3-26

Table 3-29. Tons of Wood Burned by Type................................................................ 3-27

Table 3-30. Residential Wood Burning Emission Factors (lbs/ton burned) .............. 3-27

Table 3-31. Annual Emissions from Residential Wood Burning by Device (tons) .... 3-28

Table 3-32. TAPA Annual VOC Emission Estimates from Solvent Cleaning (tons) 3-29

Table 3-33. 2000 Fire Incident Counts for Structural and Vehicle Fires .................... 3-31

Table 3-34. Emission Factors for Structural and Vehicular Fires............................... 3-31

Table 3-35. Annual TAPA Emissions from Structure and Vehicle Fires (tons) ........ 3-32

Table 3-36. TAPA Emissions from Traffic Markings ................................................ 3-33

Table 3-37. TAPA Inventory Area Source Categories Estimation Methods .............. 3-35

Table 3-38. TAPA 2000 Annual Area Source Emissions by Source Category (tons) 3-36

Table 3-39. TAPA 2005 Annual Area Source Emissions by Source Category (tons) 3-38

Table 3-40. TAPA 2010 Annual Area Source Emissions by Source Category (tons) 3-40

Table 3-41. TAPA August 22, 2000 Area Source Emissions by Source Category..... 3-43

Table 3-42. TAPA September 10, 2000 Area Source Emissions by Source Category 3-45

Table 3-43. TAPA April 24, 2001 Area Source Emissions by Source Category........ 3-47

Table 4-1. Nonroad Mobile Source Equipment Categories ........................................ 4-2

Table 4-2. NONROAD Model Equipment Allocation Parameters............................. 4-10

Table 4-3. Retail Fuel Test Data for 2000................................................................... 4-12

Table 4-4. NONROAD Model Fuel Input Parameters................................................ 4-14

Table 4-5. NONROAD Model Temperature Input Parameters................................... 4-14

Table 4-6. TAPA General Use Nonroad Equipment Emission Inventory

for 2000 (tons per year) ........................................................................... 4-15

Table 4-7. Allocation Factors used to Convert County to TAPA Emission Estimates 4-18

Table 4-8. NONROAD Model Input Parameters for Day-Specific Inventories....... 4-18

Table 4-9. TAPA General Use Nonroad Equipment Emission Inventory for

Tuesday August 22, 2000 (tons per day)........................................... 4-19

Table 4-10. NONROAD Model Monthly Activity Allocation Factors.................... 4-20

Table 4-11. NONROAD Model Day-of-Week Activity Allocation Factors............ 4-20

Table 4-12. TAPA General Use Nonroad Equipment Emission Inventory for

Sunday September 10, 2000 (tons per day)....................................... 4-22

Table 4-13. TAPA General Use Nonroad Equipment Emission Inventory for

Saturday April 14, 2001 (tons per day) ............................................. 4-23

Table 4-14. TAPA General Use Nonroad Equipment Emission Inventory for

Tuesday April 24, 2001 (tons per day).............................................. 4-24

Table 4-15. NONROAD Model Fuel Input Parameters for 2005 and 2010 ............ 4-26

Table 4-16. TAPA General Use Nonroad Equipment Emission Inventory for

2005 (tons per year)........................................................................... 4-26

# Emissions Inventories for the Tucson Air Planning Area

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# x Final Report —November 2001 

# LIST OF TABLES (Continued)

Table 4-17. TAPA General Use Nonroad Equipment Emission Inventory for

2010 (tons per year)........................................................................... 4-28

Table 4-18. 1999 FAA Commercial Air Carrier Data for TIA .................................. 4-31

Table 4-19. 1999 Aircraft Operations Data Reported by TIA.................................... 4-33

Table 4-20. 2000 Aircraft Operations Data for TIA................................................... 4-35

Table 4-21. TIA Taxi Time Data as Reported by U.S. DOT (minutes) ..................... 4-35

Table 4-22. TIA Mixing Height Data......................................................................... 4-37

Table 4-23. Statistics for Aircraft and APU PM Relations ........................................ 4-42

Table 4-24. TIA Emission Inventory for 2000 (tons per year)................................... 4-44

Table 4-25. APU Usage Rates at TIA ........................................................................ 4-46

Table 4-26. Aircraft Activity Other Than Commercial Air Carriers in 2000............. 4-47

Table 4-27. National Distribution of General Aviation and Air Taxi Aircraft .......... 4-50

Table 4-28. Comparison of LTO-Specific Emission Rates for General Aviation

and Air Taxi Aircraft (pounds per LTO)............................................. 4-50

Table 4-29. Local Distribution of General Aviation and Air Taxi Aircraft ............... 4-51

Table 4-30. EPA Default TIM Data for General Aviation and Air Taxi Aircraft

(minutes per LTO)............................................................................... 4-52

Table 4-31. Methodology Used to Develop Taxi/Idle Times for Local General

Aviation and Air Taxi Aircraft............................................................ 4-53

Table 4-32. Local Taxi/Idle TIM Data for General Aviation and Air Taxi Aircraft

(minutes per LTO)............................................................................... 4-54

Table 4-33. Local TIM Data for General Aviation and Air Taxi Aircraft

(minutes per LTO)............................................................................... 4-55

Table 4-34. Based General Aviation and Air Taxi Aircraft in 2000.......................... 4-56

Table 4-35. Local Taxi/Idle TIM Data for General Aviation and Air Taxi Aircraft

(minutes per LTO)............................................................................... 4-58

Table 4-36. Military Aircraft Distributions for 2000 ................................................. 4-61

Table 4-37. EPA Default TIM Data for Military Aircraft (minutes per LTO)........... 4-61

Table 4-38. Local and TIM Data for Military Aircraft (minutes per LTO)................ 4-62

Table 4-39. Aircraft Emissions for Operations other than Commercial Air

Carriers in 2000 (tons per year)........................................................... 4-65

Table 4-40. Total Aircraft and APU Emissions in 2000 by Airport (tons per year) .. 4-66

Table 4-41. Total Aircraft and APU Emissions in 2000 by Aircraft Type

(tons per year)...................................................................................... 4-66

Table 4-42. Other Potential Aircraft Activity Locations............................................ 4-68

Table 4-43. Day-of-Week Allocation Factors for Aircraft......................................... 4-70

Table 4-44. Aircraft Emissions for Operations other than Commercial Air Carriers

On Tuesday August 22, 2000 (tons per day)....................................... 4-71

Table 4-45. Total Aircraft and APU Emissions on Tuesday August 22, 2000 by

Airport (tons per day) .......................................................................... 4-72

Table 4-46. Total Aircraft and APU Emissions on Tuesday August 22, 2000 by

Aircraft Type (tons per day) ................................................................ 4-72

# Emissions Inventories for the Tucson Air Planning Area

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# xi Final Report —November 2001 

# LIST OF TABLES (Continued)

Table 4-47. Aircraft Emissions for Operations other than Commercial Air Carriers

On Sunday September 10, 2000 (tons per day)................................... 4-73

Table 4-48. Total Aircraft and APU Emissions on Sunday September 10, 2000

By Airport (tons per day)..................................................................... 4-74

Table 4-49. Total Aircraft and APU Emissions on Sunday September 10, 2000

By Aircraft Type (tons per day)........................................................... 4-74

Table 4-50. Aircraft Emissions for Operations other than Commercial Air Carriers

On Saturday April 14, 2001 (tons per day) ......................................... 4-75

Table 4-51. Total Aircraft and APU Emissions on Saturday April 14, 2001 by

Airport (tons per day) .......................................................................... 4-76

Table 4-52. Total Aircraft and APU Emissions on Saturday April 14, 2001 by

Aircraft Type (tons per day) ................................................................ 4-76

Table 4-53. Aircraft Emissions for Operations other than Commercial Air Carriers

On Tuesday April 24, 2001 (tons per day) .......................................... 4-78

Table 4-54. Total Aircraft and APU Emissions on Tuesday April 24, 2001 by

Airport (tons per day) .......................................................................... 4-79

Table 4-55. Total Aircraft and APU Emissions on Tuesday April 24, 2001 by

Aircraft Type (tons per day) ................................................................ 4-79

Table 4-56. Aircraft Operational Growth Ratios (Forecast Year/2000 Activity)....... 4-80

Table 4-57. Aircraft Operations Summary................................................................. 4-81

Table 4-58. Based Aircraft Summary......................................................................... 4-82

Table 4-59. Aircraft Emissions for Operations other than Commercial Air Carriers

in 2005 (tons per year)......................................................................... 4-84

Table 4-60. Total Aircraft and APU Emissions in 2005 by Airport (tons per year) .. 4-85

Table 4-61. Total Aircraft and APU Emissions in 2005 by Aircraft Type

(tons per year)...................................................................................... 4-85

Table 4-62. Aircraft Emissions for Operations other than Commercial Air Carriers

in 2010 (tons per year)......................................................................... 4-86

Table 4-63. Total Aircraft and APU Emissions in 2010 by Airport (tons per year) .. 4-87

Table 4-64. Total Aircraft and APU Emissions in 2010 by Aircraft Type

(tons per year)...................................................................................... 4-87

Table 4-65. TIA Emission Inventory for Tuesday August 22, 2000 (tons per day) ... 4-89

Table 4-66. TIA Emission Inventory for Sunday September 10, 2000

(tons per day)....................................................................................... 4-89

Table 4-67. TIA Emission Inventory for Saturday April 14, 2001 (tons per day) ..... 4-90

Table 4-68. TIA Emission Inventory for Tuesday April 24, 2001 (tons per day) ...... 4-90

Table 4-69. TIA Emission Inventory for 2005 (tons per year)................................... 4-91

Table 4-70. TIA Emission Inventory for 2010 (tons per year)................................... 4-91

Table 4-71. Aircraft Ground Support Equipment Reported by TIA .......................... 4-95

Table 4-72. Aircraft Ground Support Equipment Reported by DM .......................... 4-97

Table 4-73. Summary of Reported and Additional GSE Types................................. 4-99

Table 4-74. Summary (Average) GSE Statistics for TIA........................................... 4-100

# Emissions Inventories for the Tucson Air Planning Area

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# xii Final Report —November 2001 

# LIST OF TABLES (Concluded)

Table 4-75. Summary (Average) GSE Statistics for DM........................................... 4-101

Table 4-76. GSE Model LTO, Fuel, Temperature, and Humidity Input Parameters . 4-102

Table 4-77. GSE Emission Inventories for Calendar Year 2000 (tons per year) ....... 4-103

Table 4-78. GSE Emission Inventories for Tuesday August 22, 2000

(tons per day)....................................................................................... 4-105

Table 4-79. GSE Emission Inventories for Sunday September 10, 2000

(tons per day)....................................................................................... 4-106

Table 4-80. GSE Emission Inventories for Saturday April 14, 2001 (tons per day).. 4-109

Table 4-81. GSE Emission Inventories for Tuesday April 24, 2001 (tons per day)... 4-110

Table 4-82. GSE Emission Inventories for Calendar Year 2005 (tons per year) ....... 4-111

Table 4-83. GSE Emission Inventories for Calendar Year 2010 (tons per year) ....... 4-112

Table 4-84. Fuel Consumption Indices for Union Pacific Railroad........................... 4-115

Table 4-85. Union Pacific Railroad Gross Ton Miles for Pima County Track

Segments ............................................................................................. 4-117

Table 4-86. Union Pacific Railroad Fuel Consumption in the TAPA ....................... 4-118

Table 4-87. Forecasted Union Pacific Railroad Fuel Consumption in the TAPA ..... 4-121

Table 4-88. Locomotive Emission Control Impacts on Fleetwide Emission Rates

For Union Pacific Railroad ................................................................. 4-121

Table 4-89. Locomotive Emission Factors for Union Pacific Railroad

(pounds per gallon of fuel consumed)................................................. 4-123

Table 4-90. Annual Locomotive Emission Estimates for the TAPA (tons per year). 4-124

Table 4-91. Day-Specific Locomotive Emission Estimates for the TAPA

(tons per year)...................................................................................... 4-126

# Emissions Inventories for the Tucson Air Planning Area

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# xiii Final Report —November 2001 

# LIST OF FIGURES

Figure 2-1. Total Hours of Operation by Day of Week.............................................. 2-14

Figure 2-2. PAG 190 Hourly Activity Profiles........................................................... 2-16

Figure 2-3. PAG 095 Hourly Activity Profiles........................................................... 2-17

Figure 2-4. PAG 095 Day-of-Week Activity Profiles................................................ 2-17

Figure 2-5. PAG 095 Monthly Activity Profiles ........................................................ 2-18

Figure 3-1. TAPA 2000 VOC Emissions................................................................... 3-34

Figure 3-2. TAPA 2000 NOx Emissions ................................................................... 3-34

Figure 3-3. TAPA August 22, 2000 Area Source VOC Emissions ........................... 3-49

Figure 3-4. TAPA August 22, 2000 Area Source NOx Emissions ............................ 3-49

Figure 3-5. TAPA September 10, 2000 Area Source VOC Emissions...................... 3-50

Figure 3-6. TAPA September 10, 2000 Area Source NOx Emissions....................... 3-50

Figure 3-7. TAPA April 24, 2001 Area Source VOC Emissions............................... 3-51

Figure 3-8. TAPA April 24, 2001 Area Source NOx Emissions ............................... 3-51

Figure 4-1. Relationship Used to Estimate Aircraft PM Emission Rates .................. 4-42

Figure 4-2. Class I Railroad Freight Movement Since 1970.................................... 4-119

Figure 4-3. Class I Railroad Energy Intensity Since 1970 ....................................... 4-120

Figure 4-4. Fleetwide Locomotive Emission Reductions .......................................... 4-122

Figure 5-1. Episodic Day Inventories for the Tucson Air Planning Area .................. 5-4

Figure 5-2. Modeling Inventory Processing Input Data ............................................. 5-5

Figure 5-3. Spatial Allocation Factor Surrogate Definition for the TAPA ................ 5-7

Figure 5-4. Carbon-bond Mechanism Species Gram Molecular Weights

for Reporting ....................................................................................... 5-15

Figure 5-5. Modeling Input Emissions Totals for the August 22 nd



# Typical Summer Day (tons/day)......................................................... 5-15

Figure 5-6. Day-specific Modeling Input Emissions Totals (tons) ............................ 5-16

Figure 6-1. Diurnal Variation of Stationary Area Source NO Emissions

(g-mole/hour) in Grid Cell (105,120) from the Typical

Summer Day 2000 UAM Input File.................................................... 6-7

Figure 6-2. Gridded Stationary Area Source Paraffin Emissions (g-mole/hour)

at 1 PM from the Typical Summer Day 2000 UAM Input File .......... 6-8

# Emissions Inventories for the Tucson Air Planning Area

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# xiv Final Report —November 2001 

# ABBREVIATIONS AND ACRONYMS

ADEQ Arizona Department of Environmental Quality

ADWM Arizona Department of Weights and Measures

ALD2 High Molecular Weight Aldehydes (RCHO, R ≠ H)

AML Arc Macro Language

AQM Air Quality Model

APU Aircraft Power Unit

ARB California Air Resources Board

ASC Area Source Category Code

AT Air Taxi

CNG Compressed Natural Gas

CO Carbon Monoxide

CSF Chemical Speciation Factor

DM Davis-Monthan Air Force Base

DOT Department of Transportation

EDMS Emissions Dispersion Modeling System

EEA Energy & Environmental Analysis, Inc.

EIPP Emission Inventory Preparation Plan

EPA The U.S. Environmental Protection Agency

ETH Ethene (CH 2 

# ═ CH 2 

# )

FAA Federal Aviation Administration

FAEED FAA Aircraft Engine Emission Database

FIPS Federal Information Processing System

FIRE EPA’s Factor Information REtrieval Data System

FORM Formaldehyde (CH 2 

# ═ O)

GA General Aviation

GIS Geographical Information System

GSE Ground Support Equipment

ICAO International Civil Aviation Organization

# Emissions Inventories for the Tucson Air Planning Area

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# xv Final Report —November 2001 

# ABBREVIATIONS AND ACRONYMS

ISOP Isoprene

LPG Liquid Petroleum Gas

LTO Landing and TakeOff

NAD27 North American Datum - 1927

NCDC National Climatic Data Center

NEI US EPA National Emission Inventory

NEVES Nonroad Engine and Vehicle Emission Study

NG Natural Gas

NO Nitric Oxide

NO 2 

# Nitrogen Dioxide

NO X 

# Oxides of Nitrogen

OLE Olefinic Carbon Bond (C ═ C)

ORNL Oak Ridge National Laboratory

PAG Pima Association of Governments

PAR Paraffinic Carbon Bond (C—C)

PDEQ Pima County Department of Environmental Quality

PM Particulate Matter

PM 2.5 

# Particulate Matter less than 2.5 microns

PM 10 

# Particulate Matter less than 10 microns

RASP Regional Aviation System Plan

RVP Reid Vapor Pressure

SAF Spatial Allocation Factor

SCC Source Category Code

SCF Standard Cubic Foot

SIC Standard Industrial Classification

SIP State Implementation Plan

SO 2 

# Sulfur Dioxide

SO X 

# Oxides of Sulfur

TAF Temporal Allocation Factor

# Emissions Inventories for the Tucson Air Planning Area

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# xvi Final Report —November 2001 

# ABBREVIATIONS AND ACRONYMS

TAPA Tucson Air Planning Area

TAZ Transportation Analysis Zone

THC Total Hydrocarbon

TIA Tucson International Airport

TIM Time-In-Mode

TOL Tolulene (C 6 

# H 5 

# —CH 3 

# )

TTN EPA Technology Transfer Network

UAM Urban Airshed Model

UP Union Pacific Railroad

VOC Volatile Organic Compounds as defined by the 1990 Clean Air

Act Amendments

XYL Xylene (C 6 

# H 6 

# —(CH 3 

# ) 2 

# )

# Emissions Inventories for the Tucson Air Planning Area

PAGf-Sect4.doc 

# 4-40 Final Report – November 2001 

# (Prior material unrelated to VISTAS modeling is intentionally omitted)

While emission rates for HC, CO, and NO

x 

# are routinely measured from (new) commercial air

carrier engines under the emissions certification component of International Civil Aviation

Organization (ICAO) regulations, measurement of PM emissions is not required. As a result,

almost all aircraft engine PM emission rate data have been collected under special studies.

Currently, such data exists for only about 20 aircraft engines, with a considerable portion of these

data collected by the U.S. Air Force for military aircraft engines. While emission factors for

these engines are included in the AP-42 database upon which the FAEED and EDMS emission

inventory models were developed, they have not been included in either model due to their

limited applicability. To date, it has been standard EPA practice not to estimate PM emissions

for aircraft engines. However, since the emissions models maintain a placekeeper for PM

emission rates and include PM emission estimates for GSE, it can appear to the uninformed user

that aircraft PM emission rates are zero. As a result, aircraft are often incorrectly considered to be

insignificant PM sources even though those engines tested for PM have demonstrated significant

emission rates. This policy of exclusion by omission is not appropriate in developing an accurate

modeling inventory, even in the absence of a large emissions database. While a precise

emissions estimate cannot be made with available data, it is clear that a zero emission rate is far

from accurate.

As an alternative for this study, measured emissions data for aircraft engines that have been

tested for PM were statistically analyzed to determine whether or not a relationship to other

measured emissions parameters could be established. Intuitively, it was hoped that an inverse

relationship with NO

x 

# might be demonstrated, as such a relationship is theoretically attractive.

While the level of sophistication of the statistical analysis is constrained by the quantity of data

available, simple direct and indirect linear relationships can be examined. Because data are not

available for each test engine in each of the four LTO cycle modes and because relationships

might be expected to vary by operating mode (due to significant changes in engine and

combustion efficiency), all statistical analysis was performed for each operating mode

individually.

# Emissions Inventories for the Tucson Air Planning Area

PAGf-Sect4.doc 

# 4-41 Final Report – November 2001 

# Statistically significant relationships were found for the direct linear analysis for three of the four

LTO cycle modes. Significant in this context means that coefficient t-statistics for one or more

of the other measured pollutants (HC, CO, or NO

x 

# ) indicated a direct relationship with measured

PM (at a confidence level exceeding 95 percent). In all cases, correlation coefficients were poor

(as expected), suggesting a high level of variability and poor predictability of PM emissions for

any given engine. Nevertheless, statistics were unbiased and should provide an accurate

mechanism to initially assess PM emissions on a aggregate basis (i.e., over a range of aircraft

engine models such as those associated with an analysis for an entire set of airport operations).

Only at idle was no significant relation found, which is not surprising given relative engine

inefficiency in this mode.

The indirect linear analysis revealed a consistent and significant inverse relationship between PM

and NO

x 

# based on calculated t-statistics. Correlation coefficients continue to be poor, but

t-statistics are generally improved over those of the direct linear analysis (all developed inverse

relations, including idle, were significant at the 99 percent confidence level). In selecting the

most appropriate relationship for estimation of PM emission rates for non-tested aircraft engines,

the statistical analysis that produced the best combination of a significant t-statistic, a relatively

low root mean square error, and an intuitive engineering basis was identified. This was the

inverse NO

x 

# relationship for the takeoff (i.e., full throttle) mode of operation. Figure 4-1

illustrates the selected statistical relationship.

With this relationship established, PM emission rate data for the other aircraft operating modes

(i.e., the approach, taxi, and climbout modes) was statistically analyzed against observed PM

emission rate data for the takeoff mode. Statistically significant relations were developed for all

three modes. Table 4-23 presents the coefficients developed for these PM-to-PM regressions as

well as the statistics for the PM-to-NO

x 

# regression developed for the takeoff mode. These four

relations were used to develop a set of fleetwide PM emission factors based on measured takeoff

NO

x 

# emission rates. These emission factors were then input into the EEA aircraft emissions

model and used to generate PM emission estimates for TIA aircraft operations.

# Emissions Inventories for the Tucson Air Planning Area

PAGf-Sect4.doc 

# 4-42 Final Report – November 2001 

# FIGURE 4-1. Relationship Used to Estimate Aircraft PM Emission Rates

TABLE 4-23. Statistics for Aircraft and APU PM Relations

Statistical Parameter Takeoff PM Climbout PM Approach PM Taxi PM

Predictive Parameter 1/Takeoff NO

x 

# Takeoff PM Takeoff PM Takeoff PM

Coefficient 28.42 1.42 1.53 3.10

Coefficient t-statistic 5.1 11.8 14.9 5.7

Correlation Coefficient 0.30 0.84 0.91 0.56

F-statistic 7.4 86.1 135.7 21.9

Number of Observations 18 17 15 18



# (Subsequent material unrelated to VISTAS modeling is intentionally omitted) 0 1 2 3 4 5 6 7 8 9 10

0 5 10 15 20 25 30 35 40 45



# Takeoff NO

x 

# (lb/KlbF)Takeoff PM (lb/KlbF) 

# Diamond-shaped markers represent actual data

points used in takeoff mode PM statistical analysis.

The plotted regression line represents the statistical

best fit relation between takeoff PM and takeoff NO

x 

# , the equation for which is:

Takeoff PM = 28.42 (1/Takeoff NO

x 

# )

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix F MACTEC, Inc. 

# 232 

# APPENDIX F:

COMPARISON OF BASE F AND BASE G ON-ROAD MOBILE EMISSIONSDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix FMACTEC, Inc.233Note:Base G is equivalent to the Best and Final inventory for onroad mobile sources.Base G Onroad Mobile Emissions (Annual Tons)FIPSST 2002 2009 2018 2002 2009 2018 2002 2009 2018 2002 2009 2018 2002 2009 2018 2002 2009 2018 2002 2009 2018AL 125,768 76,065 44,503 156,460 100,693 42,622 1,303,508 902,469 594,725 6,827 802 654 3,861 3,136 2,193 2,768 2,010 1,085 5,530 6,298 6,630FL 520,757 336,707 199,050 460,503 312,321 136,040 4,493,820 3,308,863 2,263,190 20,687 2,584 2,302 11,148 9,801 7,516 7,779 6,104 3,671 17,922 21,549 23,778GA 279,975 192,773 99,464 304,309 207,024 92,113 2,699,650 1,956,263 1,303,529 12,043 1,568 1,325 7,165 6,005 4,406 5,110 3,797 2,166 10,436 12,55413,511KY 102,362 73,142 42,810 154,634 100,025 46,993 1,214,191 950,912 711,211 6,238 751 694 3,682 2,944 2,348 2,667 1,899 1,158 5,003 5,737 7,095MS 86,811 51,600 28,699 110,672 69,952 27,620 853,774 602,257 394,247 4,566 532 401 2,828 2,250 1,479 2,089 1,491 746 3,549 3,995 4,147NC 260,895 166,844 91,720 323,606 199,281 79,433 2,839,283 1,966,195 1,207,391 12,286 1,487 1,346 6,505 5,510 3,994 4,571 3,453 1,931 9,601 11,702 12,776SC 114,861 71,781 41,866 138,940 91,471 39,348 1,226,555 878,825 588,536 5,909 713 584 3,414 2,831 1,986 2,473 1,834 988 4,646 5,466 5,878TN 177,943 114,032 61,339 235,869 150,179 62,446 1,893,704 1,320,562 863,682 9,127 1,065 862 5,312 4,160 2,813 3,904 2,720 1,405 6,556 7,702 8,196VA 157,989 95,694 55,992 219,835 132,699 57,192 2,136,288 1,435,359 954,463 8,196 1,067 949 4,499 3,706 2,922 3,067 2,216 1,404 7,770 8,990 9,653WV 41,703 24,570 14,652 58,340 35,234 15,530 526,841 360,865 243,683 2,438 276 231 1,366 1,057 747 984 676 369 1,889 2,126 2,268VISTAS 1,869,063 1,203,208 680,096 2,163,168 1,398,879 599,336 19,187,613 13,682,570 9,124,656 88,316 10,844 9,348 49,780 41,400 30,403 35,411 26,200 14,922 72,902 86,118 93,932Base F Onroad Mobile (Annual Tons)FIPSST 2002 2009 2018 2002 2009 2018 2002 2009 2018 2002 2009 2018 2002 2009 2018 2002 2009 2018 2002 2009 2018AL 118,978 73,137 47,151 157,626 101,299 46,598 1,300,754 934,442 675,902 6,898 637 720 3,905 3,195 2,488 2,799 2,053 1,262 5,586 6,362 7,296FL 438,761 293,423 192,096 402,099 284,737 134,465 4,022,000 3,090,443 2,306,759 18,802 1,911 2,289 10,185 9,027 7,691 7,126 5,653 3,848 16,183 19,553 23,595GA 265,972 187,102 104,678 306,998 208,568 100,707 2,712,473 2,044,169 1,474,029 12,182 1,256 1,458 7,252 6,116 4,995 5,169 3,877 2,517 10,545 12,685 14,870KY 96,202 63,210 38,814 154,093 97,731 43,014 1,195,656 932,296 669,891 5,988 587 651 3,728 3,008 2,283 2,699 1,946 1,160 5,055 5,807 6,584MS 81,701 49,986 30,337 110,242 69,949 29,829 849,049 624,575 445,150 4,614 398 441 2,863 2,296 1,688 2,114 1,525 876 3,585 4,035 4,565NC 272,594 167,894 87,718 290,873 207,670 83,399 2,677,118 2,192,253 1,238,802 12,482 1,314 1,323 6,733 5,874 4,299 4,754 3,651 2,158 9,711 12,663 13,077SC 107,236 69,026 44,121 139,403 91,832 42,641 1,220,825 921,308 663,597 5,972 558 643 3,454 2,884 2,258 2,502 1,874 1,154 4,694 5,522 6,472TN 168,389 109,716 63,916 233,324 147,591 66,879 1,881,893 1,359,880 961,929 9,202 833 944 5,349 4,247 3,199 3,927 2,788 1,643 6,629 7,753 8,962VA 143,969 91,230 59,737 222,830 133,039 64,079 1,996,287 1,483,125 1,091,546 7,234 902 1,059 4,546 3,768 3,343 3,097 2,258 1,641 7,852 9,084 10,757WV 39,581 23,914 15,375 60,335 36,000 16,940 533,258 379,272 273,900 2,495 228 255 1,399 1,099 844 1,005 705 428 1,938 2,188 2,484VISTAS 1,733,382 1,128,638 683,942 2,077,822 1,378,416 628,551 18,389,312 13,961,764 9,801,505 85,868 8,622 9,783 49,414 41,513 33,086 35,191 26,330 16,687 71,778 85,652 98,664Emissions Change (Base G - Base F, Annual Tons) -- Positive Value Indicates Increase from Base FFIPSST 2002 2009 2018 2002 2009 2018 2002 2009 2018 2002 2009 2018 2002 2009 2018 2002 2009 2018 2002 2009 2018AL 6,789 2,928 -2,647 -1,166 -606 -3,977 2,754 -31,973 -81,178 -71 165 -66 -45 -58 -295 -31 -43 -178 -56 -63 -666FL 81,997 43,284 6,955 58,404 27,584 1,575 471,820 218,420 -43,569 1,885 672 14 963 774 -175 653 451 -177 1,738 1,996 183GA 14,003 5,671 -5,214 -2,689 -1,544 -8,594 -12,823 -87,906 -170,500 -139 312 -133 -86 -111 -589 -59 -80 -352 -109 -131 -1,359KY 6,160 9,933 3,996 541 2,294 3,979 18,534 18,615 41,319 250 164 43 -46 -65 65 -32 -47 -2 -52 -70 512MS 5,110 1,613 -1,638 430 3 -2,209 4,724 -22,319 -50,903 -48 134 -41 -35 -46 -209 -25 -34 -130 -35 -40 -419NC -11,699 -1,049 4,001 32,734 -8,389 -3,966 162,165 -226,057 -31,411 -196 174 23 -228 -364 -304 -183 -198 -226 -111 -961 -302SC 7,625 2,755 -2,255 -462 -362 -3,293 5,731 -42,483 -75,061 -63 156 -59 -40 -53 -272 -29 -40 -166 -48 -56 -594TN 9,554 4,316 -2,577 2,545 2,589 -4,433 11,811 -39,318 -98,246 -75 232 -82 -37 -87 -385 -22 -68 -238 -73 -52 -766VA 14,020 4,464 -3,744 -2,995 -340 -6,887 140,001 -47,766 -137,084 962 165 -110 -47 -62 -420 -30 -42 -237 -83 -94 -1,104WV 2,122 656 -723 -1,995 -766 -1,410 -6,416 -18,407 -30,217 -57 49 -24 -32 -42 -97 -22 -29 -59 -49 -62 -217VISTAS 135,680 74,570 -3,846 85,346 20,462 -29,215 798,301 -279,194 -676,8502,448 2,222 -435 367 -114 -2,683 219 -130 -1,764 1,123 466 -4,732Emissions Change (Base G - Base F/Base F, Annual %) -- Positive Value Indicates Increase from Base FFIPSST 2002 2009 2018 2002 2009 2018 2002 2009 2018 2002 2009 2018 2002 2009 2018 2002 2009 2018 2002 2009 2018AL 6% 4% -6% -1% -1% -9% 0% -3% -12% -1% 26% -9% -1% -2% -12% -1% -2% -14% -1% -1% -9%FL 19% 15% 4% 15% 10% 1% 12% 7% -2% 10% 35% 1% 9% 9% -2% 9% 8% -5% 11% 10% 1%GA 5% 3% -5% -1% -1% -9% 0% -4% -12% -1% 25% -9% -1% -2% -12% -1% -2% -14% -1% -1% -9%KY 6% 16% 10% 0% 2% 9% 2% 2% 6% 4% 28% 7% -1% -2% 3% -1% -2% 0% -1% -1% 8%MS 6% 3% -5% 0% 0% -7% 1% -4% -11% -1% 34% -9% -1% -2% -12% -1% -2% -15% -1% -1% -9%NC -4% -1% 5% 11% -4% -5% 6% -10% -3% -2% 13% 2% -3% -6% -7% -4% -5% -10% -1% -8% -2%SC 7% 4% -5% 0% 0% -8% 0% -5% -11% -1% 28% -9% -1% -2% -12% -1% -2% -14% -1% -1% -9%TN 6% 4% -4% 1% 2% -7% 1% -3% -10% -1% 28% -9% -1% -2% -12% -1% -2% -14% -1% -1% -9%VA 10% 5% -6% -1% 0% -11% 7% -3% -13% 13% 18% -10% -1% -2% -13% -1% -2% -14% -1% -1% -10%WV 5% 3% -5% -3% -2% -8% -1% -5% -11% -2% 21% -9% -2% -4% -12% -2% -4% -14% -3% -3% -9%VISTAS 8% 7% -1% 4% 1% -5% 4% -2% -7% 3% 26% -4% 1% 0% -8% 1% 0% -11% 2% 1% -5%VOC NOx CO SO2 PM-10 PM-2.5 NH3VOC NOx CO SO2 PM-10 PM-2.5 NH3VOC NOx CO SO2 PM-10 PM-2.5 NH3VOC NOx CO SO2 PM-10 PM-2.5 NH3Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix FMACTEC, Inc.234Annual Onroad Emissions Comparison0100,000200,000300,000400,000500,000600,000AL FL GA KY MS NC SC TN VA WV

Annual VOC Emissions (Tons)2002 BaseG2002 BaseF2009 BaseG2009 BaseF2018 BaseG2018 BaseFDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix FMACTEC, Inc.235Annual Onroad Emissions Comparison05001,0001,5002,0002,5003,0003,5004,0004,5005,000AL FL GA KY MS NC SC TN VA WV

Thousands

Annual CO Emissions (Tons)2002 BaseG2002 BaseF2009 BaseG2009 BaseF2018 BaseG2018 BaseFDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix FMACTEC, Inc.236Annual Onroad Emissions Comparison050,000100,000150,000200,000250,000300,000350,000400,000450,000500,000AL FL GA KY MS NC SC TN VA WV

Annual NOx Emissions (Tons)2002 BaseG2002 BaseF2009 BaseG2009 BaseF2018 BaseG2018 BaseFDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix FMACTEC, Inc.237Annual Onroad Emissions Comparison05,00010,00015,00020,00025,000AL FL GA KY MS NC SC TN VA WV

Annual SO2 Emissions (Tons)2002 BaseG2002 BaseF2009 BaseG2009 BaseF2018 BaseG2018 BaseFDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix FMACTEC, Inc.238Annual Onroad Emissions Comparison02,0004,0006,0008,00010,00012,000AL FL GA KY MS NC SC TN VA WV

Annual PM-10 Emissions (Tons)2002 BaseG2002 BaseF2009 BaseG2009 BaseF2018 BaseG2018 BaseFDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix FMACTEC, Inc.239Annual Onroad Emissions Comparison01,0002,0003,0004,0005,0006,0007,0008,0009,000AL FL GA KY MS NC SC TN VA WV

Annual PM-2.5 Emissions (Tons)2002 BaseG2002 BaseF2009 BaseG2009 BaseF2018 BaseG2018 BaseFDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix FMACTEC, Inc.240Annual Onroad Emissions Comparison05,00010,00015,00020,00025,000AL FL GA KY MS NC SC TN VA WV

Annual NH3 Emissions (Tons)2002 BaseG2002 BaseF2009 BaseG2009 BaseF2018 BaseG2018 BaseF

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix G 

# 241 

# APPENDIX G:

CONVERSION OF MRPO BaseM

POINT SOURCE DATA

TO SMOKE INPUT FORMAT

# Atmospheric Sciences Group

Alpine Geophysics, LLC -- 387 Pollard Mine Road -- Burnsville, NC 28714 -- (828) 675-9045 

# MEMORANDUM

To: Pat Brewer, VISTAS

From: Gregory Stella, Alpine Geophysics, LLC

Re: Conversion of MRPO BaseM Point Source Data to SMOKE Input Format

Date: 13 February 2008

The Midwest Regional Planning Organization (MRPO) periodically produces a five State emission inventory for

Illinois, Indiana, Michigan, Wisconsin, and Ohio. These data are used as the basis for various MRPO modeling and

regulatory analyses. These data are prepared with the he lp of each State’s emission inventory divisions and are felt

to be the most representative account for emissi ons activities for those States at any one time.

The most recent version prepared and distributed by MRPO is currently called BaseM. Associated with this 2005

base year inventory release is a set of growth and control factors that are used to additionally simulate future year

conditions under “On-The-Books” (base cas e or known control programs requirements to be implemented in future

years) or incremental control situations to test sensitivity or strategies which would be implemented in whole or in

part during the same future years.

The purpose of this document is to detail the technical steps that were made as part of the conversion of the MRPO

BaseM point sources files (electric generating unit [EGU] and non-EGU) into IDA format for ASIP PM-2.5 CAMx

modeling of the future year 2009. B ecause of the timing and complications relative to converting multiple and

various emission files for all source types, it was determined that only point source emissions would be converted

for processing at this time.

Data Sources and Description

A series of data files and associated documentation was obtained from MRPO staff in 2007. These files were the

input data sets for base year 2005 and growth and control factors related to MRPO’s BaseM and Round 5

inventories 6 

# . Because of the emission processing tools that MRPO currently executes for its analyses, these files are

in formats that are not read by the SMOKE emissions processor currently in use by VISTAS/ASIP modelers

(contract teams and participating states). Alpine Geophysics, under the Emissions Inventory Technical Advisor

contract, was asked to obtain and convert these data into the formats that could be used by these modeling agencies.

Through additional contact with MRPO staff, the base year 2005 non-EGU point source fi les and associated growth

and control factors necessary to forecast the data to 2009 base case conditions were identified and extracted from the

originally provided data. EGU sources were identified to be already prepared for the future year (2010 substituted

for 2009) and were based on recent IPM 3.0 model runs with incremental adjustment made by MRPO states to best

reflect expected emission controls and operating conditions . The “will do” simulation series for EGUs was identified

as “egu5b_2010.”

The main purpose of the SMOKE conversion task was to prepare five state emission inventories provided in

National Input Format (NIF) format into the IDA format required by the SMOKE model for the criteria pollutants

VOC, NOx, CO, SO2, PM-10, PM-2.5, and NH3. Annual emissions were taken directly from the NIF structured

inventories with no alternate temporal calculations perfo rmed (e.g., estimate seasonal emissions from annual or

annual from seasonal). The temporal allocation module of the SMOKE emissions processor was intended to be used

to further define temporal distribution of these emissions.

6 

# http://www.ladco.org/tech/emis/r5/round5_reports.htm

# Atmospheric Sciences Group

Alpine Geophysics, LLC -- 387 Pollard Mine Road -- Burnsville, NC 28714 -- (828) 675-9045 

# No quality assurance (QA) related to the reported valu es in the MRPO was conducted (e.g., it was assumed that

reported emission levels were correct) and therefore the QA focus of these tasks was to maintain the integrity of the

mass files in the conversion to IDA.

Each set of NIF structured data had a unique set of relatio nal tables necessary to maintain the information required

in each source sector based on its repo rting requirements. Alpine had previo usly developed scripts to read the

information from each of these relational data sets and co nvert them to the IDA struct ures required by this task.

Prior to and after each major source sector was converte d from NIF to IDA, we developed a list of emission

summary reports to check that the emissions input into the conversion process were the same as output into the IDA

formatted files.

Non-EGU Point Source Conversion

Non-EGU point source emissions from 2005 BaseM were converted to future year 2009 IDA format using the

annual emission records directly from th e NIF structured data sets and asso ciated SCC growth factors and unit,

facility, county, state, or nationally applied controls 7 

# . These controls were applied in a hierarchical fashion starting

with the most defined (unit-segment-pollutant level) th rough least defined (national-SCC-pollutant) and when a

match was found during the implementation, no additional cont rols were sought or applied to that emission record.

In other words, if a match were found at the unit-segment leve l of control, no additional controls were applied to that

segment/pollutant combination again in the forecast process. This prevented multiple control programs from being

implemented when the intent of the originally provided cont rol files were to assign a single applicable reduction.

The Round 5 factors for point sources provided by MRPO were in the RPO Data Exchange Format (RPODx) and

had growth and control factors available at the State, county , plant, unit, segment, stack, and SCC level of detail. In

order to apply these factors in a fashio n consistent with that of the MRPO utilized processing system and duplicative

of how MRPO would have generated its BaseM forecasts, a hierarchical approach was ut ilized to match and assign

growth and control values.

Growth Factor Application

Using the 2005 EM table from the BaseM inventory files in NIF format, we first selected each emissions record for

forecasting. In this conversion case, th ese EM records were limited to those em issions identified as annual using the

NIF coding convention. As noted in the limitations sectio n below, there oftentimes were emissions provided by

MRPO in a summer season convention.

We next selected the base year for application as the RPODx for growth rates allows for the flexibility of input

growth factors for multiple base year inventories. In this assignment, the base year was always 2005, as that was the

base year provided by MRPO and the future year was 2009, as selected by ASIP.

The next step was to determine the growth basis for each individual emission record of the file. This “growth basis”

is the key with which the growth factor is associated. For point sources, this key is based on a combination of FIPS,

SCC, and pollutant codes. Multiple keys are calculated fo r each individual emission reco rd and that key with the

highest resolution of matching to the growth factor file using the hierarchy identified in Table 1 below is the one

chosen to assign a growth rate to the base year emissions.

7



# http://www.ladco.org/tech/emis/r5/reports/LADCO%2 02005%20Base%20Yr%20Growth%20and%20Controls%20

Report_Final.pdf

# Atmospheric Sciences Group

Alpine Geophysics, LLC -- 387 Pollard Mine Road -- Burnsville, NC 28714 -- (828) 675-9045 

# Table 1. Point Source Growth Fact or Application Hierarchy.

Order Key or “Growth/Control Basis”

1 state/county code, 10-digit SCC, pollutant

2 state/county code, 10-digit SCC

3 state code, 10-digit SCC, pollutant

4 state code, 10-digit SCC

5 state/county code, pollutant

6 state/county code

7 state code, pollutant

8 state code

9 10-digit SCC, pollutant

10 10-digit SCC

11 Pollutant

Using the hierarchical application, growth basis, and date s (base year and alternate year ), we matched each emission

record to the growth table to obtain a growth factor. The factors are defined in the growth table as a multiplier for

the base year period that calculates the alternate year of interest. In other words, multiplying the base year emissions

value by the growth factor provides you with the emissions for the alternate year of interest.

When no match from any of the hierarchical keys was identified, a growth rate of 1.00 (no growth) was assigned.

This maintained the 2005 emission level in the future year inventory.

Control Factor Application

Similar to the process identified above for the assignment and application of growth f actors, the control factor

assignment was based on a hierarchical key, this time, however, using FIPS, plantid, pointid, stackid, segment, SCC,

and pollutant codes applied in a parallel pr ocess to the growth factor assignment.

Using the 2005 EM table from the BaseM inventory files in NIF format, we selected each annual emissions record

for forecasting. We next select ed the base year for application, and again, the base year was always 2005, as that

was the base year provided by MRPO.

Once the base year was identified, we determined the alternate y ear for our forecast. Depend ing on the specific year

used in each conversion, gr owth rates were limited to those with a base year of 2005 and a future year less than or

equal to that of our forecast. This variation in method is in tended to allow us to identify all controls implemented

prior to or during the year of interest and will consider them as viable options at the latest provided level of control.

In other words, since we selected 2009 as the future year of choice, we limit the control factor table to control

strategies implemented during or prior to 2009. If in our matching to the control factor table we find that for a

certain control basis key there is no match because a program may have been fully implemented in a prior year (say

2007), then we do not want to exclude this reduction fr om our forecast. Additionally, if we find that there are

multiple entries in the control factor table because of incr emental implementation of a rule , we select the closest year

to that of our intended forecast. So if a particular rule was incrementally implemented from 2005 through 2009 and

there were control records available for each year in between, we would select the record with the latest year to

apply in our forecast.

The next step was to determine the control basis for each individual emission record of the file. This “control basis”

is the key with which the control strategy or technology is associated. Although we developed code to support the

hierarchical application of control f actors for the BaseM emissions, all contro l factors provided by MRPO in the

Round 5 files were segment-SCC-pollutant specific. This el iminated the need for a sear ch on the key that has the

greatest resolution as all matches were at the segment-SCC-pollutant level.

# Atmospheric Sciences Group

Alpine Geophysics, LLC -- 387 Pollard Mine Road -- Burnsville, NC 28714 -- (828) 675-9045 

# Using the control basis and dates (base year and alternate year), we matched each emissi on record to the control

table to obtain a control factor. The fact ors are defined in the control table as a group of values (control efficiency,

rule effectiveness, and rule penetration) for the future year period that gets assigned to an uncontrolled future year

emission value. In other words, we first “backed out” existing base year controls from our future year emissions

estimate and then multiplied this uncontrolled value by the control factors for the alternate year of interest. These

calculations are defined in Equations 1 and 2 below.

Equation 1. Uncontrolled emissions calculation.

Emiss Unc 

# = Emiss Base 

# / (1-((CE Base 

# /100)*(RE Base 

# /100)*(RP Base 

# /100)))

Where,

Emiss Unc 

# = Uncontrolled emissions

Emiss Base 

# = Base year emissions

CE Base 

# = Base year control efficiency

RE Base 

# = Base year rule effectiveness

RP Base 

# = Base year rule penetration

Equation 2. Application of new control calculation.

Emiss New 

# = Emiss Unc 

# *(1-((CE New 

# /100)*(RE New 

# /100)*(RP New 

# /100)))

Where,

Emiss New 

# = Future year emissions

Emiss Unc 

# = Uncontrolled emissions

CE New 

# = Future year control efficiency

RE New 

# = Future year rule effectiveness

RP New 

# = Future year rule penetration

When no match from any of the hierarchical keys was iden tified, the same control effi ciency, rule efficiency, and

rule penetration values from the base year inventory were used in the calculation and the only change in emissions

would have been the result of growth factor application. In instances where PM-10 annual emissions were found to

be less than PM-2.5 annual emission values, the PM-2.5 emission values were changed to equal that of PM-10.

EGU Point Source Conversion

EGU point source emissions from the egu5b_2010 scenario (2010 IPM 3.0 run with modifications) were converted

to year 2009 IDA format using the annual emission records directly from the NIF struct ured data sets. Since these

emissions already accounted for growth and control appli cation, no additional modifi cations were required.

One ASIP requested modification for its PM-2.5 CAMx m odeling was to adjust the 2009 file to match W. H.

Sammis facility’s planned response to the control requireme nts from the consent decree USA vs. Ohio Edison; Civil

Action No: 2:99-CV-1181; March 18, 2005. These changes were not implemented in the ASIP 2009 CMAQ runs.

These adjustments for SO2 are noted in Table 2 below.

# Atmospheric Sciences Group

Alpine Geophysics, LLC -- 387 Pollard Mine Road -- Burnsville, NC 28714 -- (828) 675-9045 

# Table 2. SO2 Control Requirements from USA vs. Ohio Edison Consent Decree

Units 1-4 Induct Scrubbing

50% removal (1.1 lbs/MMBtu)

At least one unit by Sept. 30, 2008

Second unit by Dec. 31, 2008

Other two units by Dec. 31, 2009

Unit 5 Flash Dryer Absorber or Electro-Cataly tic Oxidation no later than Dec. 31, 2008

50% removal (1.1 lbs/MMBtu)

Units 6/7 Scrubber no later than December 31, 2010

95% removal (0.13 lbs/MMBtu)

Plantwide Emission cap of 101,500 by end of 2009

Emission cap of 101,500 by end of 2010

Emission cap of 29,900 by end of 2011



# Conversion Limitations

As noted above, Alpine limited our conversion to all record s in the MRPO point source f iles that were identified as

annual. In some cases the MRPO NIF files had additiona l non-annual summer season emission records configured

as a higher percentage than the annual average that was used in our emissions comparison.

In other words, the MRPO file sometimes had two emission record types that it uses for its modeling; one for the

summer period and one for the rest of the year. Since SMOKE uses temporal allocation factors to make this

summer/winter split, our converted values do not match MR PO's summertime reports. We see a high percentage

difference in the Alpine converted data compared to the MR PO output reports in these two States for the July 12

example for this reason.

Since we confirmed this difference and reason for this difference in the 2005 data sets with MRPO, our objective for

QA on the projections also included delta emissions from the projection year to the base year. Although the absolute

daily emission values (in tpd) were found to be different as noted above, in all cases, the difference between 2005

and the projection year calculations as made by Alpine was within confidence ranges of the ratio of future year to

base year as posted by MRPO. See Table 3 below. For this reason, we were convi nced that our projection

methodology is capturing the growth and control factors that MRPO applied in its emissions modeling.Atmospheric Sciences GroupAppendix G247Table 3.Emissions Comparison of ASIP Converted and MRPO Non-EGU Emissions.Comparison of ASIP Converted and MRPO Non-EGU EmissionsFIPSST State VOC NOX CO SO2 PM-10 PM-2.5 NH317 Illinois 61,760 85,142 71,725 150,506 20,315 6,256 1,05918 Indiana 48,287 65,132 339,642 82,040 22,118 12,774 78226 Michigan 36,753 85,014 67,564 55,435 13,235 6,567 78839 Ohio 31,530 67,275 212,626 116,942 15,930 10,443 3,23955 Wisconsin 31,377 36,827 43,014 60,955 456 43 346MRPO 209,707 339,390 734,570 465,878 72,054 36,082 6,214FIPSST State VOC NOX CO SO2 PM-10 PM-2.5 NH3 FIPSST State VOC NOX CO SO2 PM-10 PM-2.5 NH317 Illinois 222.3 315.1 250.9 412.3 55.6 17.1 2.9 17 Illinois 218.1 217.8 255.7 335.0 56.0 16.8 2.818 Indiana 132.3 178.4 930.5 224.8 60.6 35.0 2.1 18 Indiana 137.2 175.2 888.8 216.2 60.7 36.5 2.326 Michigan 115.8 232.4 193.6 144.9 40.8 19.3 2.4 26 Michigan 119.1 242.0 206.5 148.6 43.6 20.3 2.439 Ohio 86.4 184.3 582.5 320.4 43.6 28.6 8.9 39 Ohio 87.1 166.3 540.7 288.0 43.0 27.6 8.355 Wisconsin 86.0 100.9 117.8 167.0 1.3 0.1 0.9 55 Wisconsin 87.7 92.9 120.0 152.1 23.2 0.1 1.0MRPO 642.7 1,011.1 2,075.4 1,269.4 202.0 100.2 17.2 MRPO 649.2 894.2 2,011.7 1,139.9 226.5 101.3 16.8FIPSST State VOC NOX CO SO2 PM-10 PM-2.5 NH3 FIPSST State VOC NOX CO SO2 PM-10 PM-2.5 NH317 Illinois 29.5% 25.1% 9.8% 32.3% 28.2% 17.3% 17.0% 17 Illinois 33.6% 24.4% 12.7% 29.4% 24.7% 16.6% 16.7%18 Indiana 23.0% 19.2% 46.2% 17.6% 30.7% 35.4% 12.6% 18 Indiana 21.1% 19.6% 44.2% 19.0% 26.8% 36.0% 13.7%26 Michigan 17.5% 25.0% 9.2% 11.9% 18.4% 18.2% 12.7% 26 Michigan 18.3% 27.1% 10.3% 13.0% 19.2% 20.0% 14.3%39 Ohio 15.0% 19.8% 28.9% 25.1% 22.1% 28.9% 52.1% 39 Ohio 13.4% 18.6% 26.9% 25.3% 19.0% 27.2% 49.4%55 Wisconsin 15.0% 10.9% 5.9% 13.1% 0.6% 0.1% 5.6% 55 Wisconsin 13.5% 10.4% 6.0% 13.3% 10.2% 0.1% 6.0%MRPO 100% 100% 100% 100% 100% 100% 100% MRPO 100.0% 100.0% 100.0% 100.0% 100.0% 100.0% 100.0%ASIP 2009 July 12 Summer Daily Emissions (% of MRPO Total) 2009 July 12 Summer Daily Emissions (% of MRPO Total)ASIP 2009 Annual Emissions (Tons/Year)ASIP 2009 July 12 Summer Daily Emissions (Tons/Day) 2009 July 12 Summer Daily Emissions (Tons/Day)

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix H 

# 248 

# APPENDIX H:

COMPARISON OF EGU CONTROLS FOR COAL AND OIL/GAS UNITS

BASED ON IPM MODELING AND STATE-PROVIDED INFORMATION

FOR THE BASE G/G2 INVENTORYDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.249APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls01033 TVA COLBERT 47 1 0010 010CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber01033 TVA COLBERT 47 2 0010 011CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber01033 TVA COLBERT 47 3 0010 012CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber01033 TVA COLBERT 47 4 0010 013CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber01033 TVA COLBERT 47 5 0010 014CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber01055ALABAMA POWER COMPANYGADSDEN7 1 0002 002CoalSteamNone None None NoneNone None None None01055ALABAMA POWER COMPANYGADSDEN7 2 0002 003CoalSteamNone None None NoneNone None None None01063ALABAMA POWER COMPANYGREENE COUNTY10 1 0001 002CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber01063ALABAMA POWER COMPANYGREENE COUNTY10 2 0001 003CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber01071 TVA - WIDOWS CREEK 50 1 0008 002CoalSteamSCR SCR SCR SCR NoneNone None None01071 TVA - WIDOWS CREEK 50 2 0008 003CoalSteamSCR SCR SCR SCR NoneNone None None01071 TVA - WIDOWS CREEK 50 3 0008 004CoalSteamSCR SCR SCR SCR NoneNone None None01071 TVA - WIDOWS CREEK 50 4 0008 005CoalSteamSCR SCR SCR SCR NoneNone None None01071 TVA - WIDOWS CREEK 50 5 0008 006CoalSteamSCR SCR SCR SCR NoneNone None None01071 TVA - WIDOWS CREEK 50 6 0008 007CoalSteamSCR SCR SCR SCR NoneNone None None01071 TVA - WIDOWS CREEK 50 7 0008 008CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber01071 TVA - WIDOWS CREEK 50 8 0008 009CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.250APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls01073ALABAMA POWER COMPANY(MILLER POWER PLANT)6002 4 010730011 001CoalSteamSCRAll YearSCRSummerSCRAll YearSCRSummerNone None Scrubber None01073ALABAMA POWER COMPANY(MILLER POWER PLANT)6002 3 010730011 002CoalSteamSCRAll YearSCRSummerSCRAll YearSCRSummerNone None Scrubber None01073ALABAMA POWER COMPANY(MILLER POWER PLANT)6002 2 010730011 004CoalSteamSCRAll YearSCRSummerSCRAll YearSCRSummerNone None Scrubber None01073ALABAMA POWER COMPANY(MILLER POWER PLANT)6002 1 010730011 005CoalSteamSCRAll YearSCRSummerSCRAll YearSCRSummerNone None Scrubber None01097ALABAMA POWER COMPANYBARRY3 1 1001 002CoalSteamSNCR None SNCR SCR NoneNone None None01097ALABAMA POWER COMPANYBARRY3 2 1001 003CoalSteamSNCR None SNCR SCR NoneNone None None01097ALABAMA POWER COMPANYBARRY3 3 1001 004CoalSteamSNCR None SNCR SCR NoneNone None None01097ALABAMA POWER COMPANYBARRY3 4 1001 005CoalSteamSNCR None SNCR SCR NoneNone Scrubber Scrubber01097ALABAMA POWER COMPANYBARRY3 5 1001 006CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber01117ALABAMA POWER COMPANYE C GASTON26 1 0005 002CoalSteamNone SCR None SCR NoneNone Scrubber Scrubber01117ALABAMA POWER COMPANYE C GASTON26 2 0005 003CoalSteamNone SCR None SCR NoneNone Scrubber Scrubber01117ALABAMA POWER COMPANYE C GASTON26 3 0005 004CoalSteamNone SCR None SCR NoneNone Scrubber Scrubber01117ALABAMA POWER COMPANYE C GASTON26 4 0005 005CoalSteamNone SCR None SCR NoneNone Scrubber Scrubber01117ALABAMA POWER COMPANYE C GASTON26 5 0005 006CoalSteamSCR SCR SCR SCR None Scrubber Scrubber Scrubber01127ALABAMA POWER COMPANYGORGAS8 6 0001 004CoalSteamNone None None NoneNone None None None01127ALABAMA POWER COMPANYGORGAS8 7 0001 005CoalSteamNone None None NoneNone None None None01127ALABAMA POWER COMPANYGORGAS8 8 0001 006CoalSteamNone None None None Scrubber None Scrubber NoneDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.251APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls01127ALABAMA POWER COMPANYGORGAS8 9 0001 007CoalSteamNone None None None Scrubber None Scrubber None01127ALABAMA POWER COMPANYGORGAS8 10 0001 008CoalSteamSCR SCR SCR SCR ScrubberNone Scrubber Scrubber01129ALABAMA ELECTRIC COOPCHARLES R LOWMAN56 1 0001 002CoalSteamNone None None None Scrubber None Scrubber None01129ALABAMA ELECTRIC COOPCHARLES R LOWMAN56 2 0001 003CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber01129ALABAMA ELECTRIC COOPCHARLES R LOWMAN56 3 0001 004CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12001GAINESVILLE REGIONALUTILITIES JOHN R KELLY664 JRK6O/GSteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12001GAINESVILLE REGIONALUTILITIES JOHN R KELLY664 JRK7O/GSteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12001GAINESVILLE REGIONALUTILITIES JOHN R KELLY664 JRK8 0010005 7O/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12001CITY OF GAINESVILLE, GRUDEERHAVEN663 B1 0010006 3O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12001CITY OF GAINESVILLE, GRUDEERHAVEN663 B2 0010006 5CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber12005GULF POWER COMPANYLANSING SMITH PLANT643 1 0050014 1CoalSteamNone None SCR SCR NoneNone None Scrubber12005GULF POWER COMPANYLANSING SMITH PLANT643 2 0050014 2CoalSteamNone None SCR SCR NoneNone None Scrubber12009FLORIDA POWER & LIGHT(PCC) CAPE CANAVERAL609 PCC1 0090006 1O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12009FLORIDA POWER & LIGHT(PCC) CAPE CANAVERAL609 PCC2 0090006 2O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12011FLORIDA POWER & LIGHT(PPE) PORT EVERGLADES617 PPE1 0110036 1O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12011FLORIDA POWER & LIGHT(PPE) PORT EVERGLADES617 PPE2 0110036 2O/GSteamNone None None NoneNone None None None12011FLORIDA POWER & LIGHT(PPE) PORT EVERGLADES617 PPE3 0110036 3O/GSteamNone None None NoneNone None None NoneDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.252APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls12011FLORIDA POWER & LIGHT(PPE) PORT EVERGLADES617 PPE4 0110036 4O/GSteamNone None None NoneNone None None None12017PROGRESS ENERGY FLORIDACRYSTAL RIVER628 1 0170004 1CoalSteamNone None None NoneNone None None None12017PROGRESS ENERGY FLORIDACRYSTAL RIVER628 2 0170004 2CoalSteamNone None None NoneNone None None None12017PROGRESS ENERGY FLORIDACRYSTAL RIVER628 5 0170004 3CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber12017PROGRESS ENERGY FLORIDACRYSTAL RIVER628 4 0170004 4CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12031 SAINT JOHNS RIVER 207 1 0310045-A 16 SCR SCR SCR SCR Scrubber Scrubber Scrubber Scrubber12031 SAINT JOHNS RIVER 207 2 0310045-A 17 SCR SCR SCR SCR Scrubber Scrubber Scrubber Scrubber12031 NORTHSIDE 667 2A 0310045-B 26O/GSteamNoOperationNoOperationNoneNoOperationNoOperationNoOperationNoneNoOperation12031 NORTHSIDE 667 1A 0310045-B 27O/GSteamNoOperationNoOperationNoneNoOperationNoOperationNoOperationNoneNoOperation12031 NORTHSIDE 667 3 0310045-B 3O/GSteamNone None NoneNoOperationNone None None None12031CEDAR BAY COGENERATIONINC.10672 GEN1 0310337 1CoalSteamNone SNCR None SNCR Scrubber Scrubber Scrubber Scrubber12031CEDAR BAY COGENERATIONINC.0310337 212031CEDAR BAY COGENERATIONINC.0310337 312033GULF POWER COMPANYCRIST ELECTRIC GENERATION641 1 0330045 112033GULF POWER COMPANYCRIST ELECTRIC GENERATION641 2 0330045 2O/GSteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12033GULF POWER COMPANYCRIST ELECTRIC GENERATION641 3 0330045 3O/GSteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12033GULF POWER COMPANYCRIST ELECTRIC GENERATION641 4 0330045 4CoalSteamNone None None None None None Scrubber NoneDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.253APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls12033GULF POWER COMPANYCRIST ELECTRIC GENERATION641 5 0330045 5CoalSteamNone None None None None None Scrubber None12033GULF POWER COMPANYCRIST ELECTRIC GENERATION641 6 0330045 6CoalSteamSNCR SNCR SNCR SNCR NoneNone Scrubber None12033GULF POWER COMPANYCRIST ELECTRIC GENERATION641 7 0330045 7CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber12053Central Power and LimeIncorporated10333 GEN1 0530021 18CoalSteamNone None None None Scrubber Scrubber Scrubber Scrubber12057TAMPA ELECTRIC COMPANYBIG BEND STATION645 BB01 0570039 1CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12057TAMPA ELECTRIC COMPANYBIG BEND STATION645 BB02 0570039 2CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12057TAMPA ELECTRIC COMPANYBIG BEND STATION645 BB03 0570039 3CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12057TAMPA ELECTRIC COMPANYBIG BEND STATION645 BB04 0570039 4CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12057TAMPA ELECTRIC COMPANYF.J. GANNON STATION646 GB01 0570040 1NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12057TAMPA ELECTRIC COMPANYF.J. GANNON STATION646 GB02 0570040 2NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12057TAMPA ELECTRIC COMPANYF.J. GANNON STATION646 GB03 0570040 3NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12057TAMPA ELECTRIC COMPANYF.J. GANNON STATION646 GB04 0570040 4NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12057TAMPA ELECTRIC COMPANYF.J. GANNON STATION646 GB05 0570040 5NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12057TAMPA ELECTRIC COMPANYF.J. GANNON STATION646 GB06 0570040 6NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12061 CITY OF VERO BEACH 693 0610029 1O/GSteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12061 CITY OF VERO BEACH 693 3 0610029 3O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12061 CITY OF VERO BEACH 693 4 0610029 4O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.254APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls12063GULF POWER COMPANYSCHOLZ642 1 0630014 1CoalSteamNone None None NoneNone None None None12063GULF POWER COMPANYSCHOLZ642 2 0630014 2CoalSteamNone None None NoneNone None None None12073CITY OF TALLAHASSEEARVAH B.HOPKINS688 1 0730003 1O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12073CITY OF TALLAHASSEEARVAH B.HOPKINS688 2 0730003 4O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12081FLORIDA POWER & LIGHT(PMT) MANATEE POWER6042 PMT1 0810010 1O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12081FLORIDA POWER & LIGHT(PMT) MANATEE POWER6042 PMT2 0810010 2O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12085FLORIDA POWER & LIGHT(PMR) FPL / MARTIN6043 PMR1 0850001 1O/GSteamNone NoneNoOperationNoOperationNone NoneNoOperationNoOperation12085FLORIDA POWER & LIGHT(PMR) FPL / MARTIN6043 PMR2 0850001 2O/GSteamNone NoneNoOperationNoOperationNone NoneNoOperationNoOperation12085INDIANTOWNCOGENERATION, L.P.50976 GEN1 0850102 1CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12086FLORIDA POWER & LIGHT(PCU) CUTLER POWER610 PCU5 0250001 3O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12086FLORIDA POWER & LIGHT(PCU) CUTLER POWER610 PCU6 0250001 4O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12086FLORIDA POWER & LIGHT(PTF) TURKEY POINT621 PTP1 0250003 1O/GSteamNone NoneNoOperationNoOperationNone NoneNoOperationNoOperation12086FLORIDA POWER & LIGHT(PTF) TURKEY POINT621 PTP2 0250003 2O/GSteamNone NoneNoOperationNoOperationNone NoneNoOperationNoOperation12095ORLANDO UTILITIESCOMMISSION STANTONENERGY564 1 0950137 1CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12095ORLANDO UTILITIESCOMMISSION STANTONENERGY564 2 0950137 2CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12099FLORIDA POWER & LIGHT(PRV) RIVIERA POWE619 PRV3 0990042 3O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12099FLORIDA POWER & LIGHT(PRV) RIVIERA POWE619 PRV4 0990042 4O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.255APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls12099CITY OF LAKE WORTHUTILITIESTOM G. SMITH673 S-1 0990045 7O/GSteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12099CITY OF LAKE WORTHUTILITIESTOM G. SMITH673 S-3 0990045 9O/GSteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12101PROGRESS ENERGY FLORIDAANCLOTE8048 1 1010017 1O/GSteamNone NoneNoOperationNoOperationNone NoneNoOperationNoOperation12101PROGRESS ENERGY FLORIDAANCLOTE8048 2 1010017 2O/GSteamNone NoneNoOperationNoOperationNone NoneNoOperationNoOperation12103PROGRESS ENERGY FLORIDABARTOW634 1 1030011 1O/GSteamNoOperationNoOperationNoneNoOperationNoOperationNoOperationNoOperationNoOperation12103PROGRESS ENERGY FLORIDABARTOW634 2 1030011 2O/GSteamO/G EarlyRetirementO/G EarlyRetirementNoneO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12103PROGRESS ENERGY FLORIDABARTOW634 3 1030011 3O/GSteamNoOperationNoOperationNoneNoOperationNoOperationNoOperationNoOperationNoOperation12105LAKELAND ELECTRICCHARLES LARSEN675 7 1050003 4O/GSteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12105LAKELAND ELECTRIC C.D.MCINTOSH, JR.676 3 1050004 6CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12107SEMINOLE ELECTRICCOOPERATIVE, INC.136 1 1070025 1CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12107SEMINOLE ELECTRICCOOPERATIVE, INC.136 2 1070025 2CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12111FT PIERCE UTILITIESAUTHORITY FT PIERCE658 7 1110003 7O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12111FT PIERCE UTILITIESAUTHORITY FT PIERCE658 8 1110003 8O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12121PROGRESS ENERGY FLORIDASUWANNEE RIVER638 1 1210003 1O/GSteamO/G EarlyRetirementO/G EarlyRetirementNoneO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12121PROGRESS ENERGY FLORIDASUWANNEE RIVER638 2 1210003 2O/GSteamO/G EarlyRetirementO/G EarlyRetirementNoneO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12121PROGRESS ENERGY FLORIDASUWANNEE RIVER638 3 1210003 3O/GSteamNoOperationNoOperationNoneNoOperationNoOperationNoOperationNoOperationNoOperation12127FLORIDA POWER & LIGHT(PSN) SANFORD POWER620 PSN3 1270009 1O/GSteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.256APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls12127FLORIDA POWER & LIGHT(PSN) SANFORD POWER620 PSN4 1270009 2NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12129TALLAHASSEE CITYPURDOM GENERATINGSTATION689 7 1290001 7O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13015GEORGIA POWER COMPANY,BOWEN STEAM-ELECT703 1BLR 01500011 SG01CoalSteamSCR SCR SCR SCR None Scrubber Scrubber Scrubber13015GEORGIA POWER COMPANY,BOWEN STEAM-ELECT703 2BLR 01500011 SG02CoalSteamSCR SCR SCR SCR None Scrubber Scrubber Scrubber13015GEORGIA POWER COMPANY,BOWEN STEAM-ELECT703 3BLR 01500011 SG03CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber13015GEORGIA POWER COMPANY,BOWEN STEAM-ELECT703 4BLR 01500011 SG04CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber13021 ARKWRIGHT 699 1 0002 1NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13021 ARKWRIGHT 699 2 0002 2NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13021 ARKWRIGHT 699 3 0002 3NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13021 ARKWRIGHT 699 4 0002 4NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13051SAVANNAH ELECTRIC:KRAFT STEAM733 1 05100006 SG01CoalSteamNone None None NoneNone None None None13051SAVANNAH ELECTRIC:KRAFT STEAM733 2 05100006 SG02CoalSteamNone None None NoneNone None None None13051SAVANNAH ELECTRIC:KRAFT STEAM733 3 05100006 SG03CoalSteamNone None None SCR None None None None13051SAVANNAH ELECTRIC:KRAFT STEAM733 4 05100006 SG04O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13051 RIVERSIDE 734 11 05100018 11O/GSteamNoneNoOperationNoOperationNoOperationNoneNoOperationNoOperationNoOperation13051 RIVERSIDE 734 12 05100018 12O/GSteamNoneNoOperationNoOperationNoOperationNoneNoOperationNoOperationNoOperation13051 RIVERSIDE 734 4 05100018 4O/GSteamNone None None NoneNone None None NoneDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.257APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls13051 RIVERSIDE 734 5 05100018 5O/GSteamNoneNoOperationNoOperationNoOperationNoneNoOperationNoOperationNoOperation13051 RIVERSIDE 734 6 05100018 6O/GSteamNoneNoOperationNoOperationNoOperationNoneNoOperationNoOperationNoOperation13067GEORGIA POWER COMPANY,MCDONOUGH STEAM710 MB1 06700003 SGM1CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber13067GEORGIA POWER COMPANY,MCDONOUGH STEAM710 MB2 06700003 SGM2CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber13077GEORGIA POWER COMPANY,YATES STEAM-ELECTRIC728 Y1BR 07700001 SG01CoalSteamNone None None None Scrubber Scrubber Scrubber Scrubber13077GEORGIA POWER COMPANY,YATES STEAM-ELECTRIC728 Y2BR 07700001 SG02CoalSteamNone None None NoneNone None None None13077GEORGIA POWER COMPANY,YATES STEAM-ELECTRIC728 Y3BR 07700001 SG03CoalSteamNone None None NoneNone None None None13077GEORGIA POWER COMPANY,YATES STEAM-ELECTRIC728 Y4BR 07700001 SG04CoalSteamNone None SCR SCR NoneNone None Scrubber13077GEORGIA POWER COMPANY,YATES STEAM-ELECTRIC728 Y5BR 07700001 SG05CoalSteamNone None SCR SCR NoneNone None Scrubber13077GEORGIA POWER COMPANY,YATES STEAM-ELECTRIC728 Y6BR 07700001 SG06CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber13077GEORGIA POWER COMPANY,YATES STEAM-ELECTRIC728 Y7BR 07700001 SG07CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber13095GEORGIA POWER COMPANY,MITCHELL STEAM-ELECTRIC727 09500002 SG01NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13095GEORGIA POWER COMPANY,MITCHELL STEAM-ELECTRIC727 09500002 SG02NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13095GEORGIA POWER COMPANY,MITCHELL STEAM-ELECTRIC727 3 09500002 SG03CoalSteamNone None None NoneNone None None None13103SAVANNAH ELECTRIC:MCINTOSH STEAM - ELECTRIC6124 1 10300003 SG01CoalSteamNone None None SCR None None None None13115GEORGIA POWER COMPANY,HAMMOND STEAM-ELECTRIC708 1 11500003 SG01CoalSteamNone None SCR SCR Scrubber None Scrubber Scrubber13115GEORGIA POWER COMPANY,HAMMOND STEAM-ELECTRIC708 2 11500003 SG02CoalSteamNone None SCR SCR Scrubber None Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.258APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls13115GEORGIA POWER COMPANY,HAMMOND STEAM-ELECTRIC708 3 11500003 SG03CoalSteamNone None SCR SCR Scrubber None Scrubber Scrubber13115GEORGIA POWER COMPANY,HAMMOND STEAM-ELECTRIC708 4 11500003 SG04CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber13127GEORGIA POWER COMPANY,MCMANUS STEAM-ELECTRIC715 1 12700004 SG01O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13127GEORGIA POWER COMPANY,MCMANUS STEAM-ELECTRIC715 2 12700004 SG02O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13149GEORGIA POWER COMPANY,WANSLEY STEAM-ELECTRIC6052 1 14900001 SG01CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber13149GEORGIA POWER COMPANY,WANSLEY STEAM-ELECTRIC6052 2 14900001 SG02CoalSteamSCR SCR SCR SCR None Scrubber Scrubber Scrubber13207GEORGIA POWER COMPANY,SCHERER STEAM-ELECTRIC6257 1 20700008 SG01CoalSteamNone None None None None None Scrubber None13207GEORGIA POWER COMPANY,SCHERER STEAM-ELECTRIC6257 2 20700008 SG02CoalSteamNone None None None None None Scrubber None13207GEORGIA POWER COMPANY,SCHERER STEAM-ELECTRIC6257 3 20700008 SG03CoalSteamNone None None None None None Scrubber None13207GEORGIA POWER COMPANY,SCHERER STEAM-ELECTRIC6257 4 20700008 SG04CoalSteamNone None None None None None Scrubber None13237GEORGIA POWER COMPANY,HARLLEE BRANCH709 1 23700008 SG01CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber13237GEORGIA POWER COMPANY,HARLLEE BRANCH709 2 23700008 SG02CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber13237GEORGIA POWER COMPANY,HARLLEE BRANCH709 3 23700008 SG03CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber13237GEORGIA POWER COMPANY,HARLLEE BRANCH709 4 23700008 SG04CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber21015CINCINNATI GAS & ELECTRICEAST BEND STAT6018 2 2101500029 002CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21041KENTUCKY UTILITIES COGHENT GENERATING STATION1356 1 2104100010 001CoalSteamSCR None SCR SCR ScrubberScrubber Scrubber Scrubber21041KENTUCKY UTILITIES COGHENT GENERATING STATION1356 2 2104100010 002CoalSteamNone None SCR SCR Scrubber None Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.259APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls21041KENTUCKY UTILITIES COGHENT GENERATING STATION1356 3 2104100010 003CoalSteamSCR None SCR SCR Scrubber None Scrubber Scrubber21041KENTUCKY UTILITIES COGHENT GENERATING STATION1356 4 2104100010 004CoalSteamSCR None SCR SCR Scrubber None Scrubber Scrubber21049EAST KY POWER COOPWILLIAM C DALE PLANT1385 1 2104900003 001CoalSteamNone None None NoneNone None None None21049EAST KY POWER COOPWILLIAM C DALE PLANT1385 2 2104900003 002CoalSteamNone None None NoneNone None None None21049EAST KY POWER COOPWILLIAM C DALE PLANT1385 3 2104900003 003CoalSteamNone None None NoneNone None None None21049EAST KY POWER COOPWILLIAM C DALE PLANT1385 4 2104900003 004CoalSteamNone None None NoneNone None None None21059OWENSBORO MUNICIPALUTILELMER SMITH STATION1374 1 2105900027 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21059OWENSBORO MUNICIPALUTILELMER SMITH STATION1374 2 2105900027 002CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber Scrubber21091WESTERN KY ENERGY CORPCOLEMAN STATION1381 C1 2109100003 001CoalSteamNone None SCR SCR Scrubber None Scrubber Scrubber21091WESTERN KY ENERGY CORPCOLEMAN STATION1381 C2 2109100003 002CoalSteamNone None SCR SCR Scrubber None Scrubber Scrubber21091WESTERN KY ENERGY CORPCOLEMAN STATION1381 C3 2109100003 003CoalSteamNone None SCR SCR Scrubber None Scrubber Scrubber21101HENDERSON MUN POW &LIGHT1372 6 2110100012 002CoalSteamNone None None NoneNone None None None21101HENDERSON MUN POW &LIGHT1372 5 2110100012 5CoalSteamNone None None NoneNone None None None21111LOU GAS & ELEC,CANE RUN1363 4 0126 04CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber Scrubber21111LOU GAS & ELEC,CANE RUN1363 5 0126 05CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber Scrubber21111LOU GAS & ELEC,CANE RUN1363 6 0126 06CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber Scrubber21111LOU GAS & ELEC,MILL CREEK1364 1 0127 01CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.260APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls21111LOU GAS & ELEC,MILL CREEK1364 2 0127 02CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber Scrubber21111LOU GAS & ELEC,MILL CREEK1364 3 0127 03CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21111LOU GAS & ELEC,MILL CREEK1364 4 0127 04CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21127KENTUCKY POWER COBIG SANDY PLANT1353 BSU1 2112700003 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21127KENTUCKY POWER COBIG SANDY PLANT1353 BSU2 2112700003 002CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 1 2114500006 001CoalSteamNone None None NoneNone None None None21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 2 2114500006 002CoalSteamNone None None NoneNone None None None21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 3 2114500006 003CoalSteamNone None None NoneNone None None None21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 4 2114500006 004CoalSteamNone None None NoneNone None None None21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 5 2114500006 005CoalSteamNone None None NoneNone None None None21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 6 2114500006 006CoalSteamNone None None NoneNone None None None21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 7 2114500006 007CoalSteamNone None None NoneNone None None None21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 8 2114500006 008CoalSteamNone None None NoneNone None None None21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 9 2114500006 009CoalSteamNone None None NoneNone None None None21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 10 2114500006 016CoalSteamNone None None NoneNone None None None21161EAST KY POWER COOPSPURLOCK ST. MAYSVILLE6041 1 2116100009 001CoalSteamSCR SCR SCR SCR NoneNone Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.261APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls21161EAST KY POWER COOPSPURLOCK ST. MAYSVILLE6041 2 2116100009 002CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber21167KENTUCKY UTILITIES COBROWN FACILITY1355 1 2116700001 001CoalSteamNone None None None Scrubber None Scrubber None21167KENTUCKY UTILITIES COBROWN FACILITY1355 2 2116700001 002CoalSteamNone None SCR SCR Scrubber None Scrubber Scrubber21167KENTUCKY UTILITIES COBROWN FACILITY1355 3 2116700001 003CoalSteamNone None SCR SCR Scrubber None Scrubber Scrubber21177KENTUCKY UTILITIES COGREEN RIVER STATION1357 4 2117700001 003CoalSteamNone None None NoneNone None None None21177KENTUCKY UTILITIES COGREEN RIVER STATION1357 5 2117700001 004CoalSteamNone None None NoneNone None None None21177 TVA PARADISE STEAM PLANT 1378 1 2117700006 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21177 TVA PARADISE STEAM PLANT 1378 2 2117700006 002CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21177 TVA PARADISE STEAM PLANT 1378 3 2117700006 003CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21183WESTERN KY ENERGY CORPWILSON STATION6823 W1 2118300069 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21199EAST KY POWER COOPJOHN SHERMAN COOPER1384 1 2119900005 001CoalSteamNone None None NoneNone None None None21199EAST KY POWER COOPJOHN SHERMAN COOPER1384 2 2119900005 002CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber21223LOUISVILLE GAS & ELECTRICTRIMBLE CO GEN6071 1 2122300002 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21233 HENDERSON STATION 2 1382 H12123300001-A002CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21233 HENDERSON STATION 2 1382 H22123300001-A003CoalSteamSCR None SCR SCR ScrubberScrubber Scrubber Scrubber21233WESTERN KY ENERGY CORPREID1383 R12123300001-B001CoalSteamNone None None NoneNone None None None21233WESTERN KY ENERGY CORPGREEN STATION6639 G1 2123300052 001CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.262APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls21233WESTERN KY ENERGY CORPGREEN STATION6639 G2 2123300052 002CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber Scrubber21239KENTUCKY UTILITIESTYRONE FACILITY1361 5 2123900001 005CoalSteamNone None None NoneNone None None None28011ENTERGY MISSISSIPPI INC,DELTA PLANT2051 1 2801100031 001O/GSteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement28011ENTERGY MISSISSIPPI INC,DELTA PLANT2051 2801100031 002O/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement28011ENTERGY MISSISSIPPI INC,DELTA PLANT2051 2 2801100031 003O/GSteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement28011ENTERGY MISSISSIPPI INC,DELTA PLANT2051 2801100031 004O/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement28019CHOCTAW GENERATION LLP,RED HILLS GENERATING55076 AA001 2801900011 001ACoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber28019CHOCTAW GENERATION LLP,RED HILLS GENERATING55076 AA002 2801900011 001B None None None None None None None None28035MISSISSIPPI POWERCOMPANY,PLANT EATON2046 2803500038 001O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28035MISSISSIPPI POWERCOMPANY,PLANT EATON2046 2803500038 002O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28035MISSISSIPPI POWERCOMPANY,PLANT EATON2046 2803500038 003O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28047MISSISSIPPI POWERCOMPANY,PLANT JACK WATSON2049 1 2804700055 001O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28047MISSISSIPPI POWERCOMPANY,PLANT JACK WATSON2049 2 2804700055 002O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28047MISSISSIPPI POWERCOMPANY,PLANT JACK WATSON2049 3 2804700055 003O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28047MISSISSIPPI POWERCOMPANY,PLANT JACK WATSON2049 4 2804700055 004CoalSteamNone SCR SCR SCR NoneNone None Scrubber28047MISSISSIPPI POWERCOMPANY,PLANT JACK WATSON2049 5 2804700055 005CoalSteamNone SCR SCR SCR NoneNone Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.263APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls28049ENTERGY MISSISSIPPI INC,REX BROWN PLANT2053 4 2804900112 001O/GSteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement28049ENTERGY MISSISSIPPI INC,REX BROWN PLANT2053 3 2804900112 002O/GSteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement28059MISSISSIPPI POWERCOMPANY,PLANT DANIEL6073 1 2805900090 001CoalSteamNone SCR SCR SCR NoneNone Scrubber Scrubber28059MISSISSIPPI POWERCOMPANY,PLANT DANIEL6073 2 2805900090 002CoalSteamNone SCR SCR SCR NoneNone Scrubber Scrubber28067MOSELLE SOUTH MISSISSIPPIELECTRIC POWERASSOCIATION2070 1 2806700035 001O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28067MOSELLE SOUTH MISSISSIPPIELECTRIC POWERASSOCIATION2070 2 2806700035 002O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28067MOSELLE SOUTH MISSISSIPPIELECTRIC POWERASSOCIATION2070 3 2806700035 003O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28073RD MORROW SOUTHMISSISSIPPI ELECTRIC POWERASSOCIATION6061 1 2807300021 001CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber Scrubber28073RD MORROW SOUTHMISSISSIPPI ELECTRIC POWERASSOCIATION6061 2 2807300021 002CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber Scrubber28075MISSISSIPPI POWERCOMPANY,PLANT SWEATT2048 1 2807500032 001O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28075MISSISSIPPI POWERCOMPANY,PLANT SWEATT2048 2 2807500032 002O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28083GREENWOOD UTILITIES,HENDERSON STATION2062 H1 2808300048 001O/GSteamNone None None NoneNoOperationNoOperationNoOperationNoOperation28083GREENWOOD UTILITIES,HENDERSON STATION2062 H3 2808300048 003O/GSteamNone None None NoneNoOperationNoOperationNoOperationNoOperation28149ENTERGY MISSISSIPPI INC,BAXTER WILSON2050 1 2814900027 001O/GSteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement28149ENTERGY MISSISSIPPI INC,BAXTER WILSON2050 2 2814900027 002O/GSteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement28151ENTERGY MISSISSIPPI INC,GERALD ANDRUS8054 1 2815100048 001O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.264APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls28163YAZOO CITY PUBLIC SERVICECOMMISSION2067 3 2816300005 001O/GSteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement37017 ELIZABETHTOWN POWER, LLC 10380 UNIT1 3701700043G-17ACoalSteamNone None None NoneNone None None None37017 ELIZABETHTOWN POWER, LLC 10380 UNIT2 3701700043G-17BNone None None NoneNone None None None37019COGENTRIX OF NORTHCAROLINA INC - SOUTHPORT10378 GEN1 3701900067 G-29CoalSteamNone None None NoneNone None None None37019COGENTRIX OF NORTHCAROLINA INC - SOUTHPORT10378 GEN2 3701900067 G-30CoalSteamNone None None NoneNone None None None37021CAROLINA POWER & LIGHTASHEVILLE STEAM2706 1 628 1CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37021CAROLINA POWER & LIGHTASHEVILLE STEAM2706 2 628 2CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37025KANNAPOLIS ENERGYPARTNERS LLC3702500113 G-2CoalSteamNone None None NoneNone None None None37025KANNAPOLIS ENERGYPARTNERS LLC3702500113 G-3CoalSteamNone None None NoneNone None None None37035DUKE ENERGY CORPORATIONMARSHALL STEAM2727 3 3703500073 G-1CoalSteamSNCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37035DUKE ENERGY CORPORATIONMARSHALL STEAM2727 4 3703500073 G-2CoalSteamSNCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37035DUKE ENERGY CORPORATIONMARSHALL STEAM2727 1 3703500073 G-4CoalSteamSNCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37035DUKE ENERGY CORPORATIONMARSHALL STEAM2727 2 3703500073 G-5CoalSteamSNCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37037PROGRESS ENERGYCAROLINASCAPE FEAR2708 5 3703700063 G-1CoalSteamSNCR SNCR SNCR SNCR NoneNone Scrubber Scrubber37037PROGRESS ENERGYCAROLINASCAPE FEAR2708 6 3703700063 G-2CoalSteamSNCR SNCR SNCR SNCR NoneNone Scrubber Scrubber37071DUKE ENERGY CORPORATIONALLEN STEAM2718 1 3707100039 G-14CoalSteamSNCR SNCR SNCR SNCR ScrubberScrubber Scrubber Scrubber37071DUKE ENERGY CORPORATIONALLEN STEAM2718 2 3707100039 G-15CoalSteamSNCR SNCR SNCR SNCR ScrubberScrubber Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.265APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls37071DUKE ENERGY CORPORATIONALLEN STEAM2718 3 3707100039 G-16CoalSteamSNCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37071DUKE ENERGY CORPORATIONALLEN STEAM2718 4 3707100039 G-17CoalSteamSNCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37071DUKE ENERGY CORPORATIONALLEN STEAM2718 5 3707100039 G-18CoalSteamSNCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37071DUKE ENERGY CORPORATIONRIVERBEND STEAM2732 7 3707100040 G-17CoalSteamSNCR SNCR SNCR SNCR NoneNone None None37071DUKE ENERGY CORPORATIONRIVERBEND STEAM2732 8 3707100040 G-18CoalSteamSNCR SNCR SNCR SNCR NoneNone None None37071DUKE ENERGY CORPORATIONRIVERBEND STEAM2732 9 3707100040 G-19CoalSteamSNCR SNCR SNCR SNCR NoneNone None None37071DUKE ENERGY CORPORATIONRIVERBEND STEAM2732 10 3707100040 G-20CoalSteamSNCR SNCR SNCR SNCR NoneNone None None37083ROANOKE VALLEY ENERGYFACILITY3708300174 G-27CoalSteamNone None None NoneNone None None None37083ROANOKE VALLEY ENERGYFACILITY3708300174 G-7CoalSteamNone None None NoneNone None None None37129L V SUTTON STEAM ELECTRICPLANT2713 1 3712900036 G-187CoalSteamNone SNCR SNCR SNCR NoneNone None None37129L V SUTTON STEAM ELECTRICPLANT2713 2 3712900036 G-188CoalSteamNone SCR SCR SCR NoneNone None None37129L V SUTTON STEAM ELECTRICPLANT2713 3 3712900036 G-189CoalSteamNone SCR SCR SCR NoneScrubber Scrubber Scrubber37145CP&L - ROXBORO STEAMELECTRIC PLANT2712 1 3714500029 G-29CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37145CP&L - ROXBORO STEAMELECTRIC PLANT2712 2 3714500029 G-30CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37145CP&L - ROXBORO STEAMELECTRIC PLANT2712 3A 3714500029G-35ACoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37145CP&L - ROXBORO STEAMELECTRIC PLANT2712 3B 3714500029G-35BCoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37145CP&L - ROXBORO STEAMELECTRIC PLANT2712 4A 3714500029G-36ACoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.266APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls37145CP&L - ROXBORO STEAMELECTRIC PLANT2712 4B 3714500029G-36BCoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37145 CP&L - MAYO FACILITY 6250 1A 3714500045G-46ACoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37145 CP&L - MAYO FACILITY 6250 1B 3714500045G-46BCoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37155PROGRESS ENERGYCAROLINAS, INC., W.H.WEATHERSPOON2716 1 3715500147 G-24CoalSteamNone SNCR SNCR SNCR NoneNone None None37155PROGRESS ENERGYCAROLINAS, INC., W.H.WEATHERSPOON2716 2 3715500147 G-25CoalSteamNone SNCR SNCR SNCR NoneNone None None37155PROGRESS ENERGYCAROLINAS, INC., W.H.WEATHERSPOON2716 3 3715500147 G-26CoalSteamNone SNCR SNCR SNCR NoneNone None None37155 LUMBERTON POWER, LLC 10382 UNIT1 3715500166G-17ACoalSteamNone None None NoneNone None None None37155 LUMBERTON POWER, LLC 10382 UNIT2 3715500166G-17BNone None None NoneNone None None None37157DUKE ENERGY CORPDAN RIVER STEAM2723 3 3715700015 G-21CoalSteamNone SNCR SNCR SNCR NoneNone None None37157DUKE ENERGY CORPDAN RIVER STEAM2723 1 3715700015 G-22CoalSteamNone SNCR SNCR SNCR NoneNone None None37157DUKE ENERGY CORPDAN RIVER STEAM2723 2 3715700015 G-23CoalSteamNone SNCR SNCR SNCR NoneNone None None37159DUKE ENERGY CORPORATIONBUCK STEAM2720 5 3715900004 G-1CoalSteamNone SNCR SNCR SNCR NoneNone None None37159DUKE ENERGY CORPORATIONBUCK STEAM2720 6 3715900004 G-2CoalSteamNone SNCR SNCR SNCR NoneNone None None37159DUKE ENERGY CORPORATIONBUCK STEAM2720 7 3715900004 G-3CoalSteamSNCR SNCR SNCR SNCR NoneNone None None37159DUKE ENERGY CORPORATIONBUCK STEAM2720 8 3715900004 G-4CoalSteamSNCR SNCR SNCR SNCR NoneNone None None37159DUKE ENERGY CORPORATIONBUCK STEAM2720 9 3715900004 G-5CoalSteamSNCR SNCR SNCR SNCR NoneNone None NoneDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.267APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls37161DUKE ENERGY CORPORATIONCLIFFSIDE STEAM2721 1 3716100028 G-82CoalSteamNone SNCR SNCR SNCR NoneNone None None37161DUKE ENERGY CORPORATIONCLIFFSIDE STEAM2721 2 3716100028 G-83CoalSteamNone SNCR SNCR SNCR NoneNone None None37161DUKE ENERGY CORPORATIONCLIFFSIDE STEAM2721 3 3716100028 G-84CoalSteamNone SNCR SNCR SNCR NoneNone None None37161DUKE ENERGY CORPORATIONCLIFFSIDE STEAM2721 4 3716100028 G-85CoalSteamNone SNCR SNCR SNCR NoneNone None None37161DUKE ENERGY CORPORATIONCLIFFSIDE STEAM2721 5 3716100028 G-86CoalSteamSCR SCR SCR SCR None Scrubber Scrubber Scrubber37161DUKE ENERGY CORPORATIONCLIFFSIDE STEAM2721 6 3716100028 G-87NoOperationNot inIPMSCRNot inIPMNoOperationNot inIPMScrubberNot inIPM37161DUKE ENERGY CORPORATIONCLIFFSIDE STEAM2721 7 3716100028 G-88NoOperationNot inIPMSCRNot inIPMNoOperationNot inIPMScrubberNot inIPM37169DUKE ENERGY CORPBELEWS CREEK STEAM8042 1 3716900004 G-17CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37169DUKE ENERGY CORPBELEWS CREEK STEAM8042 2 3716900004 G-18CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37191PROGRESS ENERGYF LEE PLANT2709 1 3719100017 G-2CoalSteamNone SNCR SNCR SNCR NoneNone None None37191PROGRESS ENERGYF LEE PLANT2709 2 3719100017 G-3CoalSteamNone SNCR SNCR SNCR NoneNone None None37191PROGRESS ENERGYF LEE PLANT2709 3 3719100017 G-4CoalSteamNone SCR SCR SCR NoneScrubber None Scrubber45003 SCE&G:URQUHART 3295 URQ3 0080-0011 003CoalSteamNone None None NoneNone None None None45003 SCE&G:SRS AREA D 0080-0044 001CoalSteamNone None None NoneNone None None None45003 SCE&G:SRS AREA D 0080-0044 002 NoneNone None None None None None None45003 SCE&G:SRS AREA D 0080-0044 003 NoneNone None None None None None None45003 SCE&G:SRS AREA D 0080-0044 004 NoneNone None None None None None NoneDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.268APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls45007 DUKE ENERGY:LEE 3264 1 0200-0004 001CoalSteamNone None None NoneNone None None None45007 DUKE ENERGY:LEE 3264 2 0200-0004 002CoalSteamNone None None NoneNone None None None45007 DUKE ENERGY:LEE 3264 3 0200-0004 003CoalSteamNone None None NoneNone None None None45015 SANTEE COOPER JEFFERIES 3319 1 0420-0003 001O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation45015 SANTEE COOPER JEFFERIES 3319 2 0420-0003 002O/GSteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation45015 SANTEE COOPER JEFFERIES 3319 3 0420-0003 003CoalSteamNone SCR None SCR None None None None45015 SANTEE COOPER JEFFERIES 3319 4 0420-0003 004CoalSteamNone None None NoneNone None None None45015 SCE&G:WILLIAMS 3298 WIL1 0420-0006 001CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber45015 SANTEE COOPER CROSS 130 1 0420-0030 001CoalSteamSCR SCR SCR SCRScrubberUpgradeScrubberScrubberUpgradeScrubber45015 SANTEE COOPER CROSS 130 2 0420-0030 002CoalSteamSCR SCR SCR SCRScrubberUpgradeScrubberScrubberUpgradeScrubber45015 SANTEE COOPER CROSS 130 3 0420-0030 3CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber45015 SANTEE COOPER CROSS 130 4 0420-0030 4NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation45029 SCE&G:CANADYS 3280 CAN1 0740-0002 001CoalSteamNone None None NoneNone None None None45029 SCE&G:CANADYS 3280 CAN2 0740-0002 002CoalSteamNone None None NoneNone None None None45029 SCE&G:CANADYS 3280 CAN3 0740-0002 003CoalSteamNone None None None Scrubber None Scrubber None45031PROGRESS ENERGYROBINSON STATION3251 1 0820-0002 001CoalSteamNone None None NoneNone None None None45043 SANTEE COOPER WINYAH 6249 1 1140-0005 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.269APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls45043 SANTEE COOPER WINYAH 6249 2 1140-0005 002CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber45043 SANTEE COOPER WINYAH 6249 3 1140-0005 003CoalSteamSCR SCR SCR SCRScrubberUpgradeScrubberScrubberUpgradeScrubber45043 SANTEE COOPER WINYAH 6249 4 1140-0005 004CoalSteamSCR SCR SCR SCRScrubberUpgradeScrubberScrubberUpgradeScrubber45051 SANTEE COOPER GRAINGER 3317 1 1340-0003 001CoalSteamNone None None NoneNone None None None45051 SANTEE COOPER GRAINGER 3317 2 1340-0003 002CoalSteamNone None None NoneNone None None None45063 SCE&G:MCMEEKIN 3287 MCM1 1560-0003 001CoalSteamNone None None NoneNone None None None45063 SCE&G:MCMEEKIN 3287 MCM2 1560-0003 002CoalSteamNone None None NoneNone None None None45075 SCE&G:COPE 7210 COP1 1860-0044 001CoalSteamNone None None None Scrubber Scrubber Scrubber Scrubber45079 SCE&G:WATEREE 3297 WAT1 1900-0013 001CoalSteamSCR SCR SCR SCR Scrubber None Scrubber None45079 SCE&G:WATEREE 3297 WAT2 1900-0013 002CoalSteamSCR SCR SCR SCR ScrubberNone Scrubber Scrubber47001 TVA BULL RUN FOSSIL PLANT 3396 1 0009 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber47073TVA JOHN SEVIER FOSSILPLANT3405 1 0007 001CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber47073TVA JOHN SEVIER FOSSILPLANT3405 2 0007 002CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber47073TVA JOHN SEVIER FOSSILPLANT3405 3 0007 003CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber47073TVA JOHN SEVIER FOSSILPLANT3405 4 0007 004CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber47085TVA JOHNSONVILLE FOSSILPLANT3406 1 0011 001CoalSteamNone SCR SCR SCR NoneNone None None47085TVA JOHNSONVILLE FOSSILPLANT3406 2 0011 002CoalSteamNone SCR SCR SCR NoneNone None NoneDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.270APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls47085TVA JOHNSONVILLE FOSSILPLANT3406 3 0011 003CoalSteamNone SCR SCR SCR NoneNone None None47085TVA JOHNSONVILLE FOSSILPLANT3406 4 0011 004CoalSteamNone SCR SCR SCR NoneNone None None47085TVA JOHNSONVILLE FOSSILPLANT3406 5 0011 005CoalSteamNone SCR SCR SCR NoneNone None None47085TVA JOHNSONVILLE FOSSILPLANT3406 6 0011 006CoalSteamNone SCR SCR SCR NoneNone None None47085TVA JOHNSONVILLE FOSSILPLANT3406 7 0011 007CoalSteamNone SCR SCR SCR NoneNone None None47085TVA JOHNSONVILLE FOSSILPLANT3406 8 0011 008CoalSteamNone SCR SCR SCR NoneNone None None47085TVA JOHNSONVILLE FOSSILPLANT3406 9 0011 009CoalSteamNone SCR SCR SCR NoneNone None None47085TVA JOHNSONVILLE FOSSILPLANT3406 10 0011 010CoalSteamNone SCR SCR SCR NoneNone None None47145 TVA KINGSTON FOSSIL PLANT 3407 1 0013 001CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber47145 TVA KINGSTON FOSSIL PLANT 3407 2 0013 002CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber47145 TVA KINGSTON FOSSIL PLANT 3407 3 0013 003CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber47145 TVA KINGSTON FOSSIL PLANT 3407 4 0013 004CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber47145 TVA KINGSTON FOSSIL PLANT 3407 5 0013 005CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber47145 TVA KINGSTON FOSSIL PLANT 3407 6 0013 006CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber47145 TVA KINGSTON FOSSIL PLANT 3407 7 0013 007CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber47145 TVA KINGSTON FOSSIL PLANT 3407 8 0013 008CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber47145 TVA KINGSTON FOSSIL PLANT 3407 9 0013 009CoalSteamSCR None SCR SCR NoneNone Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.271APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls47157 ALLEN FOSSIL PLANT 3393 1 00528 Boilr1CoalSteamSCR SCR SCR SCR NoneNone None None47157 ALLEN FOSSIL PLANT 3393 2 00528 Boilr2CoalSteamSCR SCR SCR SCR NoneNone None None47157 ALLEN FOSSIL PLANT 3393 3 00528 Boilr3CoalSteamSCR SCR SCR SCR NoneNone None None47161TVA CUMBERLAND FOSSILPLANT3399 1 0011 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber47161TVA CUMBERLAND FOSSILPLANT3399 2 0011 002CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber47165 TVA GALLATIN FOSSIL PLANT 3403 1 0025 001CoalSteamNone None None None None None Scrubber Scrubber47165 TVA GALLATIN FOSSIL PLANT 3403 2 0025 002CoalSteamNone None None None None None Scrubber Scrubber47165 TVA GALLATIN FOSSIL PLANT 3403 3 0025 003CoalSteamNone None None None None None Scrubber Scrubber47165 TVA GALLATIN FOSSIL PLANT 3403 4 0025 004CoalSteamNone None None None None None Scrubber Scrubber51031DOMINION - ALTAVISTAPOWER STATION10773 1 00156 1CoalSteamSNCR SNCR SNCR SNCR ScrubberScrubber Scrubber Scrubber51031DOMINION - ALTAVISTAPOWER STATION10773 2 00156 2 None None NoneNone None None None None51041DOMINION - CHESTERFIELDPOWER STATION3797 3 00002 3CoalSteamNone None None None None None Scrubber None51041DOMINION - CHESTERFIELDPOWER STATION3797 4 00002 4CoalSteamSCR None SCR SCR NoneNone Scrubber Scrubber51041DOMINION - CHESTERFIELDPOWER STATION3797 5 00002 6CoalSteamSCR None SCR SCR NoneNone Scrubber Scrubber51041DOMINION - CHESTERFIELDPOWER STATION3797 6 00002 8CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber51065DOMINION - BREMO POWERSTATION3796 3 00001 1CoalSteamNone None None NoneNone None None None51065DOMINION - BREMO POWERSTATION3796 4 00001 2CoalSteamSNCR SNCR SNCR SNCR NoneNone None NoneDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.272APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls51071AMERICAN ELECTRIC POWERGLEN LYN3776 51 00002 1CoalSteamNone None None NoneNone None None None51071AMERICAN ELECTRIC POWERGLEN LYN3776 52 00002 2CoalSteamNone None None NoneNone None None None51071AMERICAN ELECTRIC POWERGLEN LYN3776 6 00002 3CoalSteamNone None None None None None None Scrubber51083DOMINION - CLOVER POWERSTATION7213 1 00046 1CoalSteamSNCR SNCR SNCR SNCR ScrubberScrubber Scrubber Scrubber51083DOMINION - CLOVER POWERSTATION7213 2 00046 2CoalSteamSNCR SNCR SNCR SNCR ScrubberScrubber Scrubber Scrubber51099BIRCHWOOD POWERPARTNERS, L.P.54304 1 00012 1CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber51117 Mecklenburg CogenerationFacility 52007 GEN1 00051 1CoalSteamNone None None None Scrubber Scrubber Scrubber Scrubber51117 Mecklenburg CogenerationFacility 52007 GEN2 00051 2CoalSteamNone None None None Scrubber Scrubber Scrubber Scrubber51153 DOMINION - POSSUM POINT 3804 3 00002 3CoalSteamNoneCombinedCycleNoneCombinedCycleNoneCombinedCycleNoneCombinedCycle51153 DOMINION - POSSUM POINT 3804 4 00002 4CoalSteamNoneCombinedCycleNoneCombinedCycleNoneCombinedCycleNoneCombinedCycle51153 DOMINION - POSSUM POINT 3804 5 00002 5O/GSteamNoneNoOperationNoneNoOperationNoneNoOperationNoneNoOperation51153 DOMINION - POSSUM POINT 3804 6 00002CombinedCycleCombinedCycleCombinedCycleCombinedCycleCombinedCycleCombinedCycleCombinedCycleCombinedCycleCombinedCycle51167AMERICAN ELECTRIC POWERCLINCH RIVER PLANT3775 1 00003 1CoalSteamNone None None SCR None None None Scrubber51167AMERICAN ELECTRIC POWERCLINCH RIVER PLANT3775 2 00003 2CoalSteamNone None None SCR None None None Scrubber51167AMERICAN ELECTRIC POWERCLINCH RIVER PLANT3775 3 00003 3CoalSteamNone None None SCR None None None Scrubber51175 LG&E Westmoreland Southampton 10774 GEN1 00051 1CoalSteamNone None None None Scrubber Scrubber Scrubber Scrubber51175 LG&E Westmoreland Southampton 00051 2None None None NoneNone None None NoneDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.273APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls51175 LG&E Westmoreland Southampton 00051 4None None None NoneNone None None None51199DOMINION - YORKTOWNPOWER STATION3809 3 00001 3O/GSteamSNCRNoOperationSNCRNoOperationNoneNoOperationScrubberNoOperation51199DOMINION - YORKTOWNPOWER STATION3809 2 00001 5CoalSteamSNCR SNCR SNCR SNCR NoneNone Scrubber None51199DOMINION - YORKTOWNPOWER STATION3809 1 00001 6CoalSteamSNCR SNCR SNCR SNCR NoneNone Scrubber None51510POTOMAC RIVERGENERATING STATION3788 1 00003 1CoalSteamSNCRCoal EarlyRetirementSNCRCoal EarlyRetirementNoneCoal EarlyRetirementNoneCoal EarlyRetirement51510POTOMAC RIVERGENERATING STATION3788 2 00003 2CoalSteamSNCRCoal EarlyRetirementSNCRCoal EarlyRetirementNoneCoal EarlyRetirementNoneCoal EarlyRetirement51510POTOMAC RIVERGENERATING STATION3788 3 00003 3CoalSteamSNCR None SNCR None None None None None51510POTOMAC RIVERGENERATING STATION3788 4 00003 4CoalSteamSNCR None SNCR None None None None None51510POTOMAC RIVERGENERATING STATION3788 5 00003 5CoalSteamSNCR None SNCR None None None None None51550 DOMINION - CHESAPEAKE 3803 1 00026 1CoalSteamSNCR SNCR SNCR SNCR NoneNone Scrubber None51550 DOMINION - CHESAPEAKE 3803 2 00026 2CoalSteamSNCR SNCR SNCR SNCR NoneNone Scrubber None51550 DOMINION - CHESAPEAKE 3803 3 00026 3CoalSteamSCR None SCR SCR NoneNone Scrubber Scrubber51550 DOMINION - CHESAPEAKE 3803 4 00026 4CoalSteamSCR None SCR SCR NoneNone Scrubber Scrubber54023 MOUNT STORM POWER PLANT 3954 1 0003 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54023 MOUNT STORM POWER PLANT 3954 2 0003 002CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54023 MOUNT STORM POWER PLANT 3954 3 0003 003CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54023NORTH BRANCH POWERSTATION7537 1A 0014 001CoalSteamNone None None NoneNone None None NoneDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.274APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls54023NORTH BRANCH POWERSTATION7537 1B 0014 002CoalSteamNone None None NoneNone None None None54033MONONGAHELA POWER COHARRISON3944 1 0015 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54033MONONGAHELA POWER COHARRISON3944 2 0015 002CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54033MONONGAHELA POWER COHARRISON3944 3 0015 003CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54039APPALACHIAN POWERKANAWHA RIVER PLANT3936 1 0006 001CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber54039APPALACHIAN POWERKANAWHA RIVER PLANT3936 2 0006 002CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber54049MONONGAHELA POWER CO.RIVESVILLE POWER3945 7 0009 001CoalSteamNoneCoal EarlyRetirementNoneCoal EarlyRetirementNoneCoal EarlyRetirementCoal EarlyRetirementCoal EarlyRetirement54049MONONGAHELA POWER CO.RIVESVILLE POWER3945 8 0009 002CoalSteamNoneCoal EarlyRetirementNoneCoal EarlyRetirementNoneCoal EarlyRetirementCoal EarlyRetirementCoal EarlyRetirement54049AMERICAN BITUMINOUSPOWER GRANT TOWN PLT10151 0026 001 None None None None Scrubber Scrubber Scrubber Scrubber54049 GRANT TOWN POWER PLANT 10151 GEN1 ORIS10151 GEN1CoalSteamNone None None None Scrubber Scrubber Scrubber Scrubber54051OHIO POWERMITCHELL PLANT3948 1 0005 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54051OHIO POWERMITCHELL PLANT3948 2 0005 002CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54051OHIO POWERKAMMER PLANT3947 1 0006 001CoalSteamNone SCR SCR SCR NoneScrubber Scrubber Scrubber54051OHIO POWERKAMMER PLANT3947 2 0006 002CoalSteamNone SCR SCR SCR NoneScrubber Scrubber Scrubber54051OHIO POWERKAMMER PLANT3947 3 0006 003CoalSteamNone SCR SCR SCR NoneScrubber Scrubber Scrubber54053APPALACHIAN POWER CO.PHILIP SPORN PLANT3938 11 0001 001CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber54053APPALACHIAN POWER CO.PHILIP SPORN PLANT3938 21 0001 002CoalSteamNone None SCR SCR NoneNone Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.275APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls54053APPALACHIAN POWER CO.PHILIP SPORN PLANT3938 31 0001 003CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber54053APPALACHIAN POWER CO.PHILIP SPORN PLANT3938 41 0001 004CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber54053APPALACHIAN POWER CO.PHILIP SPORN PLANT3938 51 0001 005CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber54053APPALACHIAN POWERMOUNTAINEER PLANT6264 1 0009CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54061MONONGAHELA POWER CO.FORT MARTIN POWER3943 1 0001 001CoalSteamSNCR SNCR SNCR SNCR NoneNone Scrubber Scrubber54061MONONGAHELA POWER CO.FORT MARTIN POWER3943 2 0001 002CoalSteamSNCR SNCR SNCR SNCR NoneNone Scrubber Scrubber54061MORGANTOWN ENERGYASSOCIATES0027 043 None None NoneNone None None None None54061MORGANTOWN ENERGYFACILITY10743 GEN1 ORIS10743 GEN1CoalSteamNone None None NoneNone None None None54073MONONGAHELA POWER CO.WILLOW ISLAND3946 1 0004 001CoalSteamNoneCoal EarlyRetirementNoneCoal EarlyRetirementNoneCoal EarlyRetirementCoal EarlyRetirementCoal EarlyRetirement54073MONONGAHELA POWER CO.WILLOW ISLAND3946 2 0004 002CoalSteamNone SCR SCR SCR NoneScrubber Scrubber Scrubber54073MONONGAHELA POWER COPLEASANTS POWER STATION6004 1 0005 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54073MONONGAHELA POWER COPLEASANTS POWER STATION6004 2 0005 002CoalSteamSCR SCR SCR SCR Scrubber ScrubberScrubberUpgradeScrubber54077MONONGAHELA POWER COALBRIGHT3942 1 0001 001CoalSteamNoneCoal EarlyRetirementCoal EarlyRetirementCoal EarlyRetirementNoneCoal EarlyRetirementCoal EarlyRetirementCoal EarlyRetirement54077MONONGAHELA POWER COALBRIGHT3942 2 0001 002CoalSteamNoneCoal EarlyRetirementCoal EarlyRetirementCoal EarlyRetirementNoneCoal EarlyRetirementCoal EarlyRetirementCoal EarlyRetirement54077MONONGAHELA POWER COALBRIGHT3942 3 0001 003CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber54079APPALACHIAN POWERJOHN E AMOS PLANT3935 1 0006 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54079APPALACHIAN POWERJOHN E AMOS PLANT3935 2 0006 002CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix HMACTEC, Inc.276APPENDIX H: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE BASE G/G2 INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx 2009ControlsIPMNOx 2009ControlsVISTASNOx 2018ControlsIPMNOx 2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls54079APPALACHIAN POWERJOHN E AMOS PLANT3935 3 0006 003CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber

# Documentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission Inventories

Appendix I 

# 277 

# APPENDIX I:

COMPARISON OF EGU CONTROLS FOR COAL AND OIL/GAS UNITS

BASED ON IPM MODELING AND STATE-PROVIDED INFORMATION

FOR THE B&F INVENTORYDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.278APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls01033 TVA COLBERT 47 1 0010 010CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber01033 TVA COLBERT 47 2 0010 011CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber01033 TVA COLBERT 47 3 0010 012CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber01033 TVA COLBERT 47 4 0010 013CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber01033 TVA COLBERT 47 5 0010 014CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber01055ALABAMA POWERCOMPANYGADSDEN7 1 0002 002CoalSteamNone None None NoneNone None None None01055ALABAMA POWERCOMPANYGADSDEN7 2 0002 003CoalSteamNone None None NoneNone None None None01063ALABAMA POWERCOMPANYGREENE COUNTY10 1 0001 002CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber01063ALABAMA POWERCOMPANYGREENE COUNTY10 2 0001 003CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber01071 TVA - WIDOWS CREEK 50 1 0008 002CoalSteamSCR SCR SCR SCR NoneNone None None01071 TVA - WIDOWS CREEK 50 2 0008 003CoalSteamSCR SCR SCR SCR NoneNone None None01071 TVA - WIDOWS CREEK 50 3 0008 004CoalSteamSCR SCR SCR SCR NoneNone None None01071 TVA - WIDOWS CREEK 50 4 0008 005CoalSteamSCR SCR SCR SCR NoneNone None None01071 TVA - WIDOWS CREEK 50 5 0008 006CoalSteamSCR SCR SCR SCR NoneNone None None01071 TVA - WIDOWS CREEK 50 6 0008 007CoalSteamSCR SCR SCR SCR NoneNone None None01071 TVA - WIDOWS CREEK 50 7 0008 008CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.279APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls01071 TVA - WIDOWS CREEK 50 8 0008 009CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber01073ALABAMA POWERCOMPANY(MILLER POWER PLANT)6002 4 010730011 001CoalSteamSCRAll YearSCRSummerSCRAll YearSCRSummerNone None Scrubber None01073ALABAMA POWERCOMPANY(MILLER POWER PLANT)6002 3 010730011 002CoalSteamSCRAll YearSCRSummerSCRAll YearSCRSummerNone None Scrubber None01073ALABAMA POWERCOMPANY(MILLER POWER PLANT)6002 2 010730011 004CoalSteamSCRAll YearSCRSummerSCRAll YearSCRSummerNone None Scrubber None01073ALABAMA POWERCOMPANY(MILLER POWER PLANT)6002 1 010730011 005CoalSteamSCRAll YearSCRSummerSCRAll YearSCRSummerNone None Scrubber None01097ALABAMA POWERCOMPANYBARRY3 1 1001 002CoalSteamSNCR None SNCR SCR NoneNone None None01097ALABAMA POWERCOMPANYBARRY3 2 1001 003CoalSteamSNCR None SNCR SCR NoneNone None None01097ALABAMA POWERCOMPANYBARRY3 3 1001 004CoalSteamSNCR None SNCR SCR NoneNone None None01097ALABAMA POWERCOMPANYBARRY3 4 1001 005CoalSteamSNCR None SNCR SCR NoneNone Scrubber Scrubber01097ALABAMA POWERCOMPANYBARRY3 5 1001 006CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber01117ALABAMA POWERCOMPANYE C GASTON26 1 0005 002CoalSteamNone SCR None SCR NoneNone Scrubber Scrubber01117ALABAMA POWERCOMPANYE C GASTON26 2 0005 003CoalSteamNone SCR None SCR NoneNone Scrubber Scrubber01117ALABAMA POWERCOMPANYE C GASTON26 3 0005 004CoalSteamNone SCR None SCR NoneNone Scrubber Scrubber01117ALABAMA POWERCOMPANYE C GASTON26 4 0005 005CoalSteamNone SCR None SCR NoneNone Scrubber Scrubber01117ALABAMA POWERCOMPANYE C GASTON26 5 0005 006CoalSteamSCR SCR SCR SCR None Scrubber Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.280APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls01127ALABAMA POWERCOMPANYGORGAS8 6 0001 004CoalSteamNone None None NoneNone None None None01127ALABAMA POWERCOMPANYGORGAS8 7 0001 005CoalSteamNone None None NoneNone None None None01127ALABAMA POWERCOMPANYGORGAS8 8 0001 006CoalSteamNone None None None Scrubber None Scrubber None01127ALABAMA POWERCOMPANYGORGAS8 9 0001 007CoalSteamNone None None None Scrubber None Scrubber None01127ALABAMA POWERCOMPANYGORGAS8 10 0001 008CoalSteamSCR SCR SCR SCR ScrubberNone Scrubber Scrubber01129ALABAMA ELECTRIC COOPCHARLES R LOWMAN56 1 0001 002CoalSteamNone None None None Scrubber None Scrubber None01129ALABAMA ELECTRIC COOPCHARLES R LOWMAN56 2 0001 003CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber01129ALABAMA ELECTRIC COOPCHARLES R LOWMAN56 3 0001 004CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12001GAINESVILLE REGIONALUTILITIES JOHN R KELLY664 JRK6 O/G SteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12001GAINESVILLE REGIONALUTILITIES JOHN R KELLY664 JRK7 O/G SteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12001GAINESVILLE REGIONALUTILITIES JOHN R KELLY664 JRK8 0010005 7O/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12001CITY OF GAINESVILLE, GRUDEERHAVEN663 B1 0010006 3 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12001CITY OF GAINESVILLE, GRUDEERHAVEN663 B2 0010006 5CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber12005GULF POWER COMPANYLANSING SMITH PLANT643 1 0050014 1CoalSteamNone None SCR SCR NoneNone None Scrubber12005GULF POWER COMPANYLANSING SMITH PLANT643 2 0050014 2CoalSteamNone None SCR SCR NoneNone None Scrubber12009FLORIDA POWER & LIGHT(PCC) CAPE CANAVERAL609 PCC1 0090006 1 O/G Steam NoneNoOperationNoneNoOperationNoneNoOperationNoneNoOperationDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.281APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls12009FLORIDA POWER & LIGHT(PCC) CAPE CANAVERAL609 PCC2 0090006 2 O/G Steam NoneNoOperationNoneNoOperationNoneNoOperationNoneNoOperation12011FLORIDA POWER & LIGHT(PPE) PORT EVERGLADES617 PPE1 0110036 1 O/G Steam NoneNoOperationNoneNoOperationNoneNoOperationNoneNoOperation12011FLORIDA POWER & LIGHT(PPE) PORT EVERGLADES617 PPE2 0110036 2 O/G Steam None None None None None None None None12011FLORIDA POWER & LIGHT(PPE) PORT EVERGLADES617 PPE3 0110036 3 O/G Steam None None None None None None None None12011FLORIDA POWER & LIGHT(PPE) PORT EVERGLADES617 PPE4 0110036 4 O/G Steam None None None None None None None None12017PROGRESS ENERGYFLORIDACRYSTAL RIVER628 1 0170004 1CoalSteamNone None None NoneNone None None None12017PROGRESS ENERGYFLORIDACRYSTAL RIVER628 2 0170004 2CoalSteamNone None None NoneNone None None None12017PROGRESS ENERGYFLORIDACRYSTAL RIVER628 5 0170004 3CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber12017PROGRESS ENERGYFLORIDACRYSTAL RIVER628 4 0170004 4CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12031 SAINT JOHNS RIVER 207 1 0310045-A 16 SCR SCR SCR SCR Scrubber Scrubber Scrubber Scrubber12031 SAINT JOHNS RIVER 207 2 0310045-A 17 SCR SCR SCR SCR Scrubber Scrubber Scrubber Scrubber12031 NORTHSIDE 667 2A 0310045-B 26 O/G Steam NoneNoOperationNoneNoOperationNoneNoOperationNoneNoOperation12031 NORTHSIDE 667 1A 0310045-B 27 O/G Steam NoneNoOperationNoneNoOperationNoneNoOperationNoneNoOperation12031 NORTHSIDE 667 3 0310045-B 3 O/G Steam None None NoneNoOperationNone None None None12031CEDAR BAYCOGENERATION INC.10672 GEN1 0310337 1CoalSteamNone SNCR None SNCR Scrubber Scrubber Scrubber Scrubber12031CEDAR BAYCOGENERATION INC.0310337 2 None NoneDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.282APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls12031CEDAR BAYCOGENERATION INC.0310337 3 None None12033GULF POWER COMPANYCRIST ELECTRICGENERATION641 1 0330045 112033GULF POWER COMPANYCRIST ELECTRICGENERATION641 2 0330045 2 O/G SteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12033GULF POWER COMPANYCRIST ELECTRICGENERATION641 3 0330045 3 O/G SteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12033GULF POWER COMPANYCRIST ELECTRICGENERATION641 4 0330045 4CoalSteamNone None None None Scrubber None Scrubber None12033GULF POWER COMPANYCRIST ELECTRICGENERATION641 5 0330045 5CoalSteamNone None None None Scrubber None Scrubber None12033GULF POWER COMPANYCRIST ELECTRICGENERATION641 6 0330045 6CoalSteamSNCR SNCR SNCR SNCR Scrubber None Scrubber None12033GULF POWER COMPANYCRIST ELECTRICGENERATION641 7 0330045 7CoalSteamSCR SCR SCR SCR ScrubberNone Scrubber Scrubber12053Central Power and LimeIncorporated10333 GEN1 0530021 18CoalSteamNone None None None Scrubber Scrubber Scrubber Scrubber12057TAMPA ELECTRIC COMPANYBIG BEND STATION645 BB01 0570039 1CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12057TAMPA ELECTRIC COMPANYBIG BEND STATION645 BB02 0570039 2CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12057TAMPA ELECTRIC COMPANYBIG BEND STATION645 BB03 0570039 3CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12057TAMPA ELECTRIC COMPANYBIG BEND STATION645 BB04 0570039 4CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12057TAMPA ELECTRIC COMPANYF.J. GANNON STATION646 GB01 0570040 1NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12057TAMPA ELECTRIC COMPANYF.J. GANNON STATION646 GB02 0570040 2NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12057TAMPA ELECTRIC COMPANYF.J. GANNON STATION646 GB03 0570040 3NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.283APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls12057TAMPA ELECTRIC COMPANYF.J. GANNON STATION646 GB04 0570040 4NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12057TAMPA ELECTRIC COMPANYF.J. GANNON STATION646 GB05 0570040 5NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12057TAMPA ELECTRIC COMPANYF.J. GANNON STATION646 GB06 0570040 6NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12061 CITY OF VERO BEACH 693 0610029 1 O/G SteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12061 CITY OF VERO BEACH 693 3 0610029 3 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12061 CITY OF VERO BEACH 693 4 0610029 4 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12063GULF POWER COMPANYSCHOLZ642 1 0630014 1CoalSteamNone NoneShutDownNone None NoneShutDownNone12063GULF POWER COMPANYSCHOLZ642 2 0630014 2CoalSteamNone NoneShutDownNone None NoneShutDownNone12073CITY OF TALLAHASSEEARVAH B.HOPKINS688 1 0730003 1 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12073CITY OF TALLAHASSEEARVAH B.HOPKINS688 2 0730003 4 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12081FLORIDA POWER & LIGHT(PMT) MANATEE POWER6042 PMT1 0810010 1 O/G Steam NoneNoOperationNoneNoOperationNoneNoOperationNoneNoOperation12081FLORIDA POWER & LIGHT(PMT) MANATEE POWER6042 PMT2 0810010 2 O/G Steam NoneNoOperationNoneNoOperationNoneNoOperationNoneNoOperation12085FLORIDA POWER & LIGHT(PMR) FPL / MARTIN6043 PMR1 0850001 1 O/G Steam None None NoneNoOperationNone None NoneNoOperation12085FLORIDA POWER & LIGHT(PMR) FPL / MARTIN6043 PMR2 0850001 2 O/G Steam None None NoneNoOperationNone None NoneNoOperation12085INDIANTOWNCOGENERATION, L.P.50976 GEN1 0850102 1CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12086FLORIDA POWER & LIGHT(PCU) CUTLER POWER610 PCU5 0250001 3 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.284APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls12086FLORIDA POWER & LIGHT(PCU) CUTLER POWER610 PCU6 0250001 4 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12086FLORIDA POWER & LIGHT(PTF) TURKEY POINT621 PTP1 0250003 1 O/G Steam None None NoneNoOperationNone None NoneNoOperation12086FLORIDA POWER & LIGHT(PTF) TURKEY POINT621 PTP2 0250003 2 O/G Steam None None NoneNoOperationNone None NoneNoOperation12095ORLANDO UTILITIESCOMMISSION STANTONENERGY564 1 0950137 1CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12095ORLANDO UTILITIESCOMMISSION STANTONENERGY564 2 0950137 2CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12099FLORIDA POWER & LIGHT(PRV) RIVIERA POWE619 PRV3 0990042 3 O/G Steam NoneNoOperationNoneNoOperationNoneNoOperationNoneNoOperation12099FLORIDA POWER & LIGHT(PRV) RIVIERA POWE619 PRV4 0990042 4 O/G Steam NoneNoOperationNoneNoOperationNoneNoOperationNoneNoOperation12099CITY OF LAKE WORTHUTILITIESTOM G. SMITH673 S-1 0990045 7 O/G SteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12099CITY OF LAKE WORTHUTILITIESTOM G. SMITH673 S-3 0990045 9 O/G SteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12101PROGRESS ENERGYFLORIDAANCLOTE8048 1 1010017 1 O/G Steam None None NoneNoOperationNone None NoneNoOperation12101PROGRESS ENERGYFLORIDAANCLOTE8048 2 1010017 2 O/G Steam None None NoneNoOperationNone None NoneNoOperation12103PROGRESS ENERGYFLORIDABARTOW634 1 1030011 1 O/G SteamNoOperationNoOperationNoneNoOperationNoOperationNoOperationNoOperationNoOperation12103PROGRESS ENERGYFLORIDABARTOW634 2 1030011 2 O/G SteamO/G EarlyRetirementO/G EarlyRetirementNoneO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12103PROGRESS ENERGYFLORIDABARTOW634 3 1030011 3 O/G SteamNoOperationNoOperationNoneNoOperationNoOperationNoOperationNoOperationNoOperation12105LAKELAND ELECTRICCHARLES LARSEN675 7 1050003 4 O/G SteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12105LAKELAND ELECTRIC C.D.MCINTOSH, JR.676 3 1050004 1CoalSteamNoneCombined CycleNoneCombined CycleNoneCombined CycleNoneCombined CycleDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.285APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls12105LAKELAND ELECTRIC C.D.MCINTOSH, JR.676 3 1050004 5CoalSteamNoneCombined CycleNoneCombined CycleNoneCombined CycleNoneCombined Cycle12105LAKELAND ELECTRIC C.D.MCINTOSH, JR.676 3 1050004 6CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12107SEMINOLE ELECTRICCOOPERATIVE, INC.136 1 1070025 1CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12107SEMINOLE ELECTRICCOOPERATIVE, INC.136 2 1070025 2CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber12111FT PIERCE UTILITIESAUTHORITY FT PIERCE658 7 1110003 7 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12111FT PIERCE UTILITIESAUTHORITY FT PIERCE658 8 1110003 8 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12121PROGRESS ENERGYFLORIDA SUWANNEE RIVER638 1 1210003 1 O/G SteamO/G EarlyRetirementO/G EarlyRetirementNoneO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementNoneO/G EarlyRetirement12121PROGRESS ENERGYFLORIDA SUWANNEE RIVER638 2 1210003 2 O/G SteamO/G EarlyRetirementO/G EarlyRetirementNoneO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementNoneO/G EarlyRetirement12121PROGRESS ENERGYFLORIDA SUWANNEE RIVER638 3 1210003 3 O/G Steam NoneNoOperationNoneNoOperationNoneNoOperationNoneNoOperation12127FLORIDA POWER & LIGHT(PSN) SANFORD POWER620 PSN3 1270009 1 O/G SteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement12127FLORIDA POWER & LIGHT(PSN) SANFORD POWER620 PSN4 1270009 2NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation12129TALLAHASSEE CITYPURDOM GENERATINGSTATION689 7 1290001 7 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13015GEORGIA POWER COMPANY,BOWEN STEAM-ELECT703 1BLR 01500011 SG01CoalSteamSCR SCR SCR SCR None Scrubber Scrubber Scrubber13015GEORGIA POWER COMPANY,BOWEN STEAM-ELECT703 2BLR 01500011 SG02CoalSteamSCR SCR SCR SCR None Scrubber Scrubber Scrubber13015GEORGIA POWER COMPANY,BOWEN STEAM-ELECT703 3BLR 01500011 SG03CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber13015GEORGIA POWER COMPANY,BOWEN STEAM-ELECT703 4BLR 01500011 SG04CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.286APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls13021 ARKWRIGHT 699 1 0002 1NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13021 ARKWRIGHT 699 2 0002 2NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13021 ARKWRIGHT 699 3 0002 3NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13021 ARKWRIGHT 699 4 0002 4NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13051SAVANNAH ELECTRIC:KRAFT STEAM733 1 05100006 SG01CoalSteamNone None None NoneNone None None None13051SAVANNAH ELECTRIC:KRAFT STEAM733 2 05100006 SG02CoalSteamNone None None NoneNone None None None13051SAVANNAH ELECTRIC:KRAFT STEAM733 3 05100006 SG03CoalSteamNone None None SCR None None None None13051SAVANNAH ELECTRIC:KRAFT STEAM733 4 05100006 SG04 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13051 RIVERSIDE 734 11 05100018 11 O/G Steam NoneNoOperationNoOperationNoOperationNoneNoOperationNoOperationNoOperation13051 RIVERSIDE 734 12 05100018 12 O/G Steam NoneNoOperationNoOperationNoOperationNoneNoOperationNoOperationNoOperation13051 RIVERSIDE 734 4 05100018 4 O/G Steam NoneNone None None NoneNone None None13051 RIVERSIDE 734 5 05100018 5 O/G Steam NoneNoOperationNoOperationNoOperationNoneNoOperationNoOperationNoOperation13051 RIVERSIDE 734 6 05100018 6 O/G Steam NoneNoOperationNoOperationNoOperationNoneNoOperationNoOperationNoOperation13067GEORGIA POWER COMPANY,MCDONOUGH STEAM710 MB1 06700003 SGM1CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber13067GEORGIA POWER COMPANY,MCDONOUGH STEAM710 MB2 06700003 SGM2CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber13077GEORGIA POWER COMPANY,YATES STEAM-ELECTRIC728 Y1BR 07700001 SG01CoalSteamNone None None None Scrubber Scrubber Scrubber Scrubber13077GEORGIA POWER COMPANY,YATES STEAM-ELECTRIC728 Y2BR 07700001 SG02CoalSteamNone None None NoneNone None None NoneDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.287APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls13077GEORGIA POWER COMPANY,YATES STEAM-ELECTRIC728 Y3BR 07700001 SG03CoalSteamNone None None NoneNone None None None13077GEORGIA POWER COMPANY,YATES STEAM-ELECTRIC728 Y4BR 07700001 SG04CoalSteamNone None SCR SCR NoneNone None Scrubber13077GEORGIA POWER COMPANY,YATES STEAM-ELECTRIC728 Y5BR 07700001 SG05CoalSteamNone None SCR SCR NoneNone None Scrubber13077GEORGIA POWER COMPANY,YATES STEAM-ELECTRIC728 Y6BR 07700001 SG06CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber13077GEORGIA POWER COMPANY,YATES STEAM-ELECTRIC728 Y7BR 07700001 SG07CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber13095GEORGIA POWER COMPANY,MITCHELL STEAM-ELECTRIC727 09500002 SG01NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13095GEORGIA POWER COMPANY,MITCHELL STEAM-ELECTRIC727 09500002 SG02NoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13095GEORGIA POWER COMPANY,MITCHELL STEAM-ELECTRIC727 3 09500002 SG03CoalSteamNone None None NoneNone None None None13103SAVANNAH ELECTRIC:MCINTOSH STEAM -ELECTRIC6124 1 10300003 SG01CoalSteamNone None None SCR None None None None13115GEORGIA POWER COMPANY,HAMMOND STEAMELECTRIC708 1 11500003 SG01CoalSteamNone None SCR SCR Scrubber None Scrubber Scrubber13115GEORGIA POWER COMPANY,HAMMOND STEAMELECTRIC708 2 11500003 SG02CoalSteamNone None SCR SCR Scrubber None Scrubber Scrubber13115GEORGIA POWER COMPANY,HAMMOND STEAMELECTRIC708 3 11500003 SG03CoalSteamNone None SCR SCR Scrubber None Scrubber Scrubber13115GEORGIA POWER COMPANY,HAMMOND STEAMELECTRIC708 4 11500003 SG04CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber13127GEORGIA POWER COMPANY,MCMANUS STEAMELECTRIC715 1 12700004 SG01 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13127GEORGIA POWER COMPANY,MCMANUS STEAMELECTRIC715 2 12700004 SG02 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation13149GEORGIA POWER COMPANY,WANSLEY STEAM-ELECTRIC6052 1 14900001 SG01CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.288APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls13149GEORGIA POWER COMPANY,WANSLEY STEAM-ELECTRIC6052 2 14900001 SG02CoalSteamSCR SCR SCR SCR None Scrubber Scrubber Scrubber13207GEORGIA POWER COMPANY,SCHERER STEAM-ELECTRIC6257 1 20700008 SG01CoalSteamNone None None None None None Scrubber None13207GEORGIA POWER COMPANY,SCHERER STEAM-ELECTRIC6257 2 20700008 SG02CoalSteamNone None None None None None Scrubber None13207GEORGIA POWER COMPANY,SCHERER STEAM-ELECTRIC6257 3 20700008 SG03CoalSteamNone None None None None None Scrubber None13207GEORGIA POWER COMPANY,SCHERER STEAM-ELECTRIC6257 4 20700008 SG04CoalSteamNone None None None None None Scrubber None13237GEORGIA POWER COMPANY,HARLLEE BRANCH709 1 23700008 SG01CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber13237GEORGIA POWER COMPANY,HARLLEE BRANCH709 2 23700008 SG02CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber13237GEORGIA POWER COMPANY,HARLLEE BRANCH709 3 23700008 SG03CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber13237GEORGIA POWER COMPANY,HARLLEE BRANCH709 4 23700008 SG04CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber13297GENERIC UNIT900113GSC13ORIS900113GSC13CoalSteamNoOperationNoOperationSCR SCRNoOperationNoOperationScrubber Scrubber21015CINCINNATI GAS &ELECTRICEAST BEND STAT6018 2 2101500029 002CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21041KENTUCKY UTILITIES COGHENT GENERATINGSTATION1356 1 2104100010 001CoalSteamSCR None SCR SCR ScrubberScrubber Scrubber Scrubber21041KENTUCKY UTILITIES COGHENT GENERATINGSTATION1356 2 2104100010 002CoalSteamNone None SCR SCR Scrubber None Scrubber Scrubber21041KENTUCKY UTILITIES COGHENT GENERATINGSTATION1356 3 2104100010 003CoalSteamSCR None SCR SCR Scrubber None Scrubber Scrubber21041KENTUCKY UTILITIES COGHENT GENERATINGSTATION1356 4 2104100010 004CoalSteamSCR None SCR SCR Scrubber None Scrubber Scrubber21049EAST KY POWER COOPWILLIAM C DALE PLANT1385 1 2104900003 001CoalSteamNone None None NoneNone None None NoneDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.289APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls21049EAST KY POWER COOPWILLIAM C DALE PLANT1385 2 2104900003 002CoalSteamNone None None NoneNone None None None21049EAST KY POWER COOPWILLIAM C DALE PLANT1385 3 2104900003 003CoalSteamNone None None NoneNone None None None21049EAST KY POWER COOPWILLIAM C DALE PLANT1385 4 2104900003 004CoalSteamNone None None NoneNone None None None21059OWENSBORO MUNICIPALUTILELMER SMITH STATION1374 1 2105900027 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21059OWENSBORO MUNICIPALUTILELMER SMITH STATION1374 2 2105900027 002CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber Scrubber21091WESTERN KY ENERGY CORPCOLEMAN STATION1381 C1 2109100003 001CoalSteamNone None SCR SCR Scrubber None Scrubber Scrubber21091WESTERN KY ENERGY CORPCOLEMAN STATION1381 C2 2109100003 002CoalSteamNone None SCR SCR Scrubber None Scrubber Scrubber21091WESTERN KY ENERGY CORPCOLEMAN STATION1381 C3 2109100003 003CoalSteamNone None SCR SCR Scrubber None Scrubber Scrubber21091GENERIC UNIT900121GSC21ORIS900121GSC21CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21101HENDERSON MUN POW &LIGHT1372 6 2110100012 002CoalSteamNone None None NoneNone None None None21101HENDERSON MUN POW &LIGHT1372 5 2110100012 5CoalSteamNone None None NoneNone None None None21111LOU GAS & ELEC,CANE RUN1363 4 0126 04CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber Scrubber21111LOU GAS & ELEC,CANE RUN1363 5 0126 05CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber Scrubber21111LOU GAS & ELEC,CANE RUN1363 6 0126 06CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber Scrubber21111LOU GAS & ELEC,MILL CREEK1364 1 0127 01CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber Scrubber21111LOU GAS & ELEC,MILL CREEK1364 2 0127 02CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.290APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls21111LOU GAS & ELEC,MILL CREEK1364 3 0127 03CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21111LOU GAS & ELEC,MILL CREEK1364 4 0127 04CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21127KENTUCKY POWER COBIG SANDY PLANT1353 BSU1 2112700003 001CoalSteamNone SCR SCR SCR NoneScrubber Scrubber Scrubber21127KENTUCKY POWER COBIG SANDY PLANT1353 BSU2 2112700003 002CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 1 2114500006 001CoalSteamNone None None NoneNone None None None21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 2 2114500006 002CoalSteamNone None None NoneNone None None None21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 3 2114500006 003CoalSteamNone None None NoneNone None None None21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 4 2114500006 004CoalSteamNone None None NoneNone None None None21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 5 2114500006 005CoalSteamNone None None NoneNone None None None21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 6 2114500006 006CoalSteamNone None None NoneNone None None None21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 7 2114500006 007CoalSteamNone None None NoneNone None None None21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 8 2114500006 008CoalSteamNone None None NoneNone None None None21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 9 2114500006 009CoalSteamNone None None NoneNone None None None21145TVA-ENVIRONMENTALAFFAIRSSHAWNEE PLANT1379 10 2114500006 016CoalSteamNone None None NoneNone None None None21161EAST KY POWER COOPSPURLOCK ST. MAYSVILLE6041 1 2116100009 001CoalSteamSCR SCR SCR SCR ScrubberNone Scrubber Scrubber21161EAST KY POWER COOPSPURLOCK ST. MAYSVILLE6041 2 2116100009 002CoalSteamSCR SCR SCR SCR ScrubberNone Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.291APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls21167KENTUCKY UTILITIES COBROWN FACILITY1355 1 2116700001 001CoalSteamNone None None None Scrubber None Scrubber None21167KENTUCKY UTILITIES COBROWN FACILITY1355 2 2116700001 002CoalSteamNone None SCR SCR Scrubber None Scrubber Scrubber21167KENTUCKY UTILITIES COBROWN FACILITY1355 3 2116700001 003CoalSteamNone None SCR SCR Scrubber None Scrubber Scrubber21177KENTUCKY UTILITIES COGREEN RIVER STATION1357 4 2117700001 003CoalSteamNone None None NoneNone None None None21177KENTUCKY UTILITIES COGREEN RIVER STATION1357 5 2117700001 004CoalSteamNone None None NoneNone None None None21177TVA PARADISE STEAMPLANT1378 1 2117700006 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21177TVA PARADISE STEAMPLANT1378 2 2117700006 002CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21177TVA PARADISE STEAMPLANT1378 3 2117700006 003CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21183WESTERN KY ENERGY CORPWILSON STATION6823 W1 2118300069 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21199EAST KY POWER COOPJOHN SHERMAN COOPER1384 1 2119900005 001CoalSteamNone None None None None None Scrubber None21199EAST KY POWER COOPJOHN SHERMAN COOPER1384 2 2119900005 002CoalSteamNone SCR SCR SCR NoneNone Scrubber Scrubber21223LOUISVILLE GAS &ELECTRICTRIMBLE CO GEN6071 1 2122300002 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21233 HENDERSON STATION 2 1382 H12123300001-A002CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber21233 HENDERSON STATION 2 1382 H22123300001-A003CoalSteamSCR None SCR SCR ScrubberScrubber Scrubber Scrubber21233WESTERN KY ENERGY CORPREID1383 R12123300001-B001CoalSteamNone None None NoneNone None None None21233WESTERN KY ENERGY CORPGREEN STATION6639 G1 2123300052 001CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.292APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls21233WESTERN KY ENERGY CORPGREEN STATION6639 G2 2123300052 002CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber Scrubber21239KENTUCKY UTILITIESTYRONE FACILITY1361 5 2123900001 005CoalSteamNone None None NoneNone None None None28011ENTERGY MISSISSIPPI INC,DELTA PLANT2051 1 2801100031 001 O/G Steam NoneO/G EarlyRetirementNoneO/G EarlyRetirementNoneO/G EarlyRetirementNoneO/G EarlyRetirement28011ENTERGY MISSISSIPPI INC,DELTA PLANT2051 2801100031 002 NoneO/G EarlyRetirementNoneO/G EarlyRetirementNoneO/G EarlyRetirementNoneO/G EarlyRetirement28011ENTERGY MISSISSIPPI INC,DELTA PLANT2051 2 2801100031 003 O/G Steam NoneO/G EarlyRetirementNoneO/G EarlyRetirementNoneO/G EarlyRetirementNoneO/G EarlyRetirement28011ENTERGY MISSISSIPPI INC,DELTA PLANT2051 2801100031 004 NoneO/G EarlyRetirementNoneO/G EarlyRetirementNoneO/G EarlyRetirementNoneO/G EarlyRetirement28019CHOCTAW GENERATIONLLP,RED HILLS GENERATING55076 AA001 2801900011 001ACoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber28019CHOCTAW GENERATIONLLP,RED HILLS GENERATING55076 AA002 2801900011 001B28035MISSISSIPPI POWERCOMPANY,PLANT EATON2046 2803500038 001 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28035MISSISSIPPI POWERCOMPANY,PLANT EATON2046 2803500038 002 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28035MISSISSIPPI POWERCOMPANY,PLANT EATON2046 2803500038 003 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28047MISSISSIPPI POWERCOMPANY,PLANT JACK WATSON2049 1 2804700055 001 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28047MISSISSIPPI POWERCOMPANY,PLANT JACK WATSON2049 2 2804700055 002 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28047MISSISSIPPI POWERCOMPANY,PLANT JACK WATSON2049 3 2804700055 003 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28047MISSISSIPPI POWERCOMPANY,PLANT JACK WATSON2049 4 2804700055 004CoalSteamNone SCR SCR SCR NoneNone None ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.293APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls28047MISSISSIPPI POWERCOMPANY,PLANT JACK WATSON2049 5 2804700055 005CoalSteamNone SCR SCR SCR NoneNone Scrubber Scrubber28049ENTERGY MISSISSIPPI INC,REX BROWN PLANT2053 4 2804900112 001 O/G Steam NoneO/G EarlyRetirementNoneO/G EarlyRetirementNoneO/G EarlyRetirementNoneO/G EarlyRetirement28049ENTERGY MISSISSIPPI INC,REX BROWN PLANT2053 3 2804900112 002 O/G Steam NoneO/G EarlyRetirementNoneO/G EarlyRetirementNoneO/G EarlyRetirementNoneO/G EarlyRetirement28059MISSISSIPPI POWERCOMPANY,PLANT DANIEL6073 1 2805900090 001CoalSteamNone SCR SCR SCR NoneNone Scrubber Scrubber28059MISSISSIPPI POWERCOMPANY,PLANT DANIEL6073 2 2805900090 002CoalSteamNone SCR SCR SCR NoneNone Scrubber Scrubber28067MOSELLE SOUTHMISSISSIPPI ELECTRICPOWER ASSOCIATION2070 1 2806700035 001 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28067MOSELLE SOUTHMISSISSIPPI ELECTRICPOWER ASSOCIATION2070 2 2806700035 002 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28067MOSELLE SOUTHMISSISSIPPI ELECTRICPOWER ASSOCIATION2070 3 2806700035 003 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28073RD MORROW SOUTHMISSISSIPPI ELECTRICPOWER ASSOCIATION6061 1 2807300021 001CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber Scrubber28073RD MORROW SOUTHMISSISSIPPI ELECTRICPOWER ASSOCIATION6061 2 2807300021 002CoalSteamNone None SCR SCR Scrubber Scrubber Scrubber Scrubber28075MISSISSIPPI POWERCOMPANY,PLANT SWEATT2048 1 2807500032 001 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28075MISSISSIPPI POWERCOMPANY,PLANT SWEATT2048 2 2807500032 002 O/G SteamNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperationNoOperation28083GREENWOOD UTILITIES,HENDERSON STATION2062 H1 2808300048 001 O/G SteamNone None None NoneNoOperationNoOperationNoOperationNoOperation28083GREENWOOD UTILITIES,HENDERSON STATION2062 H3 2808300048 003 O/G SteamNone None None NoneNoOperationNoOperationNoOperationNoOperation28149ENTERGY MISSISSIPPI INC,BAXTER WILSON2050 1 2814900027 001 O/G Steam NoneO/G EarlyRetirementNoneO/G EarlyRetirementNoneO/G EarlyRetirementNoneO/G EarlyRetirementDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.294APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls28149ENTERGY MISSISSIPPI INC,BAXTER WILSON2050 2 2814900027 002 O/G Steam NoneO/G EarlyRetirementNoneO/G EarlyRetirementNoneO/G EarlyRetirementNoneO/G EarlyRetirement28151ENTERGY MISSISSIPPI INC,GERALD ANDRUS8054 1 2815100048 001 O/G Steam NoneNoOperationNoneNoOperationNoneNoOperationNoneNoOperation28163YAZOO CITY PUBLICSERVICE COMMISSION2067 3 2816300005 001 O/G SteamO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirementO/G EarlyRetirement37017ELIZABETHTOWN POWER,LLC10380 UNIT1 3701700043 G-17ACoalSteamNone None None NoneNone None None None37017ELIZABETHTOWN POWER,LLC10380 UNIT2 3701700043 G-17B None NoneNone None NoneNone None None37019COGENTRIX OF NORTHCAROLINA INC -SOUTHPORT10378 GEN1 3701900067 G-29CoalSteamNone None None NoneNone None None None37019COGENTRIX OF NORTHCAROLINA INC -SOUTHPORT10378 GEN2 3701900067 G-30CoalSteamNone None None NoneNone None None None37021CAROLINA POWER & LIGHTASHEVILLE STEAM2706 1 628 1CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37021CAROLINA POWER & LIGHTASHEVILLE STEAM2706 2 628 2CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37025KANNAPOLIS ENERGYPARTNERS LLC3702500113 G-2CoalSteamNone None None NoneNone None None None37025KANNAPOLIS ENERGYPARTNERS LLC3702500113 G-3CoalSteamNone None None NoneNone None None None37035DUKE ENERGYCORPORATIONMARSHALL STEAM2727 3 3703500073 G-1CoalSteamSNCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37035DUKE ENERGYCORPORATIONMARSHALL STEAM2727 4 3703500073 G-2CoalSteamSNCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37035DUKE ENERGYCORPORATIONMARSHALL STEAM2727 1 3703500073 G-4CoalSteamSNCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37035DUKE ENERGYCORPORATIONMARSHALL STEAM2727 2 3703500073 G-5CoalSteamSNCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37037PROGRESS ENERGYCAROLINASCAPE FEAR2708 5 3703700063 G-1CoalSteamSNCR SNCR SNCR SNCR None NoneFurnaceSorbentInjectionScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.295APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls37037PROGRESS ENERGYCAROLINASCAPE FEAR2708 6 3703700063 G-2CoalSteamSNCR SNCR SNCR SNCR None NoneFurnaceSorbentInjectionScrubber37045GENERIC UNIT900137GSC37ORIS900137GSC37CoalSteamNoOperationNoOperationSCR SCRNoOperationNoOperationScrubber Scrubber37055GENERIC UNIT900237GSC37ORIS900237GSC37CoalSteamNoOperationNoOperationSCR SCRNoOperationNoOperationScrubber Scrubber37055GENERIC UNIT900337GSC37ORIS900337GSC37CoalSteamNoOperationNoOperationSCR SCRNoOperationNoOperationScrubber Scrubber37061GENERIC UNIT900437GSC37ORIS900437GSC37CoalSteamNoOperationNoOperationSCR SCRNoOperationNoOperationScrubber Scrubber37083GENERIC UNIT900537GSC37ORIS900537GSC37CoalSteamNoOperationNoOperationSCR SCRNoOperationNoOperationScrubber Scrubber37083GENERIC UNIT900637GSC37ORIS900637GSC37CoalSteamNoOperationNoOperationSCR SCRNoOperationNoOperationScrubber Scrubber37071DUKE ENERGYCORPORATIONALLEN STEAM2718 1 3707100039 G-14CoalSteamSNCR SNCR SNCR SNCR ScrubberScrubber Scrubber Scrubber37071DUKE ENERGYCORPORATIONALLEN STEAM2718 2 3707100039 G-15CoalSteamSNCR SNCR SNCR SNCR ScrubberScrubber Scrubber Scrubber37071DUKE ENERGYCORPORATIONALLEN STEAM2718 3 3707100039 G-16CoalSteamSNCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37071DUKE ENERGYCORPORATIONALLEN STEAM2718 4 3707100039 G-17CoalSteamSNCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37071DUKE ENERGYCORPORATIONALLEN STEAM2718 5 3707100039 G-18CoalSteamSNCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37071DUKE ENERGYCORPORATIONRIVERBEND STEAM2732 7 3707100040 G-17CoalSteamSNCR SNCR SNCR SNCR NoneNone None None37071DUKE ENERGYCORPORATIONRIVERBEND STEAM2732 8 3707100040 G-18CoalSteamSNCR SNCR SNCR SNCR NoneNone None None37071DUKE ENERGYCORPORATIONRIVERBEND STEAM2732 9 3707100040 G-19CoalSteamSNCR SNCR SNCR SNCR NoneNone None None37071DUKE ENERGYCORPORATIONRIVERBEND STEAM2732 10 3707100040 G-20CoalSteamSNCR SNCR SNCR SNCR NoneNone None NoneDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.296APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls37083ROANOKE VALLEY ENERGYFACILITY3708300174 G-27CoalSteamNone None None NoneNone None None None37083ROANOKE VALLEY ENERGYFACILITY3708300174 G-7CoalSteamNone None None NoneNone None None None37129L V SUTTON STEAMELECTRIC PLANT2713 1 3712900036 G-187CoalSteamNone SNCR SNCR SNCR NoneNone None None37129L V SUTTON STEAMELECTRIC PLANT2713 2 3712900036 G-188CoalSteamNone SCR SCR SCR NoneNone None None37129L V SUTTON STEAMELECTRIC PLANT2713 3 3712900036 G-189CoalSteamNone SCR SCR SCR NoneScrubber Scrubber Scrubber37145CP&L - ROXBORO STEAMELECTRIC PLANT2712 1 3714500029 G-29CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37145CP&L - ROXBORO STEAMELECTRIC PLANT2712 2 3714500029 G-30CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37145CP&L - ROXBORO STEAMELECTRIC PLANT2712 3A 3714500029 G-35ACoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37145CP&L - ROXBORO STEAMELECTRIC PLANT2712 3B 3714500029 G-35BCoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37145CP&L - ROXBORO STEAMELECTRIC PLANT2712 4A 3714500029 G-36ACoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37145CP&L - ROXBORO STEAMELECTRIC PLANT2712 4B 3714500029 G-36BCoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37145 CP&L - MAYO FACILITY 6250 1A 3714500045 G-46ACoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37145 CP&L - MAYO FACILITY 6250 1B 3714500045 G-46BCoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37155PROGRESS ENERGYCAROLINAS, INC., W.H.WEATHERSPOON2716 1 3715500147 G-24CoalSteamNone SNCR SNCR SNCR NoneNone None None37155PROGRESS ENERGYCAROLINAS, INC., W.H.WEATHERSPOON2716 2 3715500147 G-25CoalSteamNone SNCR SNCR SNCR NoneNone None None37155PROGRESS ENERGYCAROLINAS, INC., W.H.WEATHERSPOON2716 3 3715500147 G-26CoalSteamNone SNCR SNCR SNCR NoneNone None NoneDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.297APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls37155 LUMBERTON POWER, LLC 10382 UNIT1 3715500166 G-17ACoalSteamNone None None NoneNone None None None37155 LUMBERTON POWER, LLC 10382 UNIT2 3715500166 G-17BNone None None NoneNone None None None37157DUKE ENERGY CORPDAN RIVER STEAM2723 3 3715700015 G-21CoalSteamNone SNCR SNCR SNCR NoneNone None None37157DUKE ENERGY CORPDAN RIVER STEAM2723 1 3715700015 G-22CoalSteamNone SNCR SNCR SNCR NoneNone None None37157DUKE ENERGY CORPDAN RIVER STEAM2723 2 3715700015 G-23CoalSteamNone SNCR SNCR SNCR NoneNone None None37159DUKE ENERGYCORPORATIONBUCK STEAM2720 5 3715900004 G-1CoalSteamNone SNCR SNCR SNCR NoneNone None None37159DUKE ENERGYCORPORATIONBUCK STEAM2720 6 3715900004 G-2CoalSteamNone SNCR SNCR SNCR NoneNone None None37159DUKE ENERGYCORPORATIONBUCK STEAM2720 7 3715900004 G-3CoalSteamSNCR SNCR SNCR SNCR NoneNone None None37159DUKE ENERGYCORPORATIONBUCK STEAM2720 8 3715900004 G-4CoalSteamSNCR SNCR SNCR SNCR NoneNone None None37159DUKE ENERGYCORPORATIONBUCK STEAM2720 9 3715900004 G-5CoalSteamSNCR SNCR SNCR SNCR NoneNone None None37161DUKE ENERGYCORPORATIONCLIFFSIDE STEAM2721 1 3716100028 G-82CoalSteamNone SNCR SNCR SNCR NoneNone None None37161DUKE ENERGYCORPORATIONCLIFFSIDE STEAM2721 2 3716100028 G-83CoalSteamNone SNCR SNCR SNCR NoneNone None None37161DUKE ENERGYCORPORATIONCLIFFSIDE STEAM2721 3 3716100028 G-84CoalSteamNone SNCR SNCR SNCR NoneNone None None37161DUKE ENERGYCORPORATIONCLIFFSIDE STEAM2721 4 3716100028 G-85CoalSteamNone SNCR SNCR SNCR NoneNone None None37161DUKE ENERGYCORPORATIONCLIFFSIDE STEAM2721 5 3716100028 G-86CoalSteamSCR SCR SCR SCR None Scrubber Scrubber Scrubber37161DUKE ENERGYCORPORATION2721 6 3716100028 G-87CoalSteamNoOperationNot inIPMSCRNot inIPMNoOperationNot inIPMScrubberNot inIPMDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.298APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018ControlsCLIFFSIDE STEAM37161DUKE ENERGYCORPORATIONCLIFFSIDE STEAM2721 7 3716100028 G-88NoOperationNot inIPMNoOperationNot inIPMNoOperationNot inIPMNoOperationNot inIPM37169DUKE ENERGY CORPBELEWS CREEK STEAM8042 1 3716900004 G-17CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37169DUKE ENERGY CORPBELEWS CREEK STEAM8042 2 3716900004 G-18CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber37191PROGRESS ENERGYF LEE PLANT2709 1 3719100017 G-2CoalSteamNone SNCR SNCR SNCR NoneNone None None37191PROGRESS ENERGYF LEE PLANT2709 2 3719100017 G-3CoalSteamNone SNCR SNCR SNCR NoneNone None None37191PROGRESS ENERGYF LEE PLANT2709 3 3719100017 G-4CoalSteamNone SCR SCR SCR NoneScrubber None Scrubber45003 SCE&G:URQUHART 3295 URQ3 0080-0011 003CoalSteamNone None None NoneNone None None None45003 SCE&G:SRS AREA D 0080-0044 001CoalSteamNone None None NoneNone None None None45003 SCE&G:SRS AREA D 0080-0044 002None None None None45003 SCE&G:SRS AREA D 0080-0044 003None None None None45003 SCE&G:SRS AREA D 0080-0044 004None None None None45007 DUKE ENERGY:LEE 3264 1 0200-0004 001CoalSteamNone None None NoneNone None None None45007 DUKE ENERGY:LEE 3264 2 0200-0004 002CoalSteamNone None None NoneNone None None None45007 DUKE ENERGY:LEE 3264 3 0200-0004 003CoalSteamNone None None NoneNone None None None45015 SANTEE COOPER JEFFERIES 3319 1 0420-0003 001 O/G SteamNoOperationNoOperationNoneNoOperationNoOperationNoOperationNoneNoOperationDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.299APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls45015 SANTEE COOPER JEFFERIES 3319 2 0420-0003 002 O/G SteamNoOperationNoOperationNoneNoOperationNoOperationNoOperationNoneNoOperation45015 SANTEE COOPER JEFFERIES 3319 3 0420-0003 003CoalSteamNone SCR None SCR None None None None45015 SANTEE COOPER JEFFERIES 3319 4 0420-0003 004CoalSteamNone None None NoneNone None None None45015 SCE&G:WILLIAMS 3298 WIL1 0420-0006 001CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber45015 SANTEE COOPER CROSS 130 1 0420-0030 001CoalSteamSCR SCR SCR SCRScrubberUpgradeScrubberScrubberUpgradeScrubber45015 SANTEE COOPER CROSS 130 2 0420-0030 002CoalSteamSCR SCR SCR SCRScrubberUpgradeScrubberScrubberUpgradeScrubber45015 SANTEE COOPER CROSS 130 3 0420-0030 3CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber45015 SANTEE COOPER CROSS 130 4 0420-0030 4CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber45029 SCE&G:CANADYS 3280 CAN1 0740-0002 001CoalSteamNone None None NoneNone None None None45029 SCE&G:CANADYS 3280 CAN2 0740-0002 002CoalSteamNone None None NoneNone None None None45029 SCE&G:CANADYS 3280 CAN3 0740-0002 003CoalSteamNone None None None Scrubber None Scrubber None45031PROGRESS ENERGYROBINSON STATION3251 1 0820-0002 001CoalSteamNone None None NoneNone None None None45043 SANTEE COOPER WINYAH 6249 1 1140-0005 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber45043 SANTEE COOPER WINYAH 6249 2 1140-0005 002CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber45043 SANTEE COOPER WINYAH 6249 3 1140-0005 003CoalSteamSCR SCR SCR SCRScrubberUpgradeScrubberScrubberUpgradeScrubber45043 SANTEE COOPER WINYAH 6249 4 1140-0005 004CoalSteamSCR SCR SCR SCRScrubberUpgradeScrubberScrubberUpgradeScrubber45051 SANTEE COOPER GRAINGER 3317 1 1340-0003 001CoalSteamNone None None NoneNone None None NoneDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.300APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls45051 SANTEE COOPER GRAINGER 3317 2 1340-0003 002CoalSteamNone None None NoneNone None None None45063 SCE&G:MCMEEKIN 3287 MCM1 1560-0003 001CoalSteamNone None None NoneNone None None None45063 SCE&G:MCMEEKIN 3287 MCM2 1560-0003 002CoalSteamNone None None NoneNone None None None45075 SCE&G:COPE 7210 COP1 1860-0044 001CoalSteamNone None None None Scrubber Scrubber Scrubber Scrubber45079 SCE&G:WATEREE 3297 WAT1 1900-0013 001CoalSteamSCR SCR SCR SCR Scrubber None Scrubber None45079 SCE&G:WATEREE 3297 WAT2 1900-0013 002CoalSteamSCR SCR SCR SCR ScrubberNone Scrubber Scrubber45029GENERIC UNIT900145GSC45ORIS900145GSC45CoalSteamNoOperationNoOperationSCR SCRNoOperationNoOperationScrubber Scrubber45031GENERIC UNIT900245GSC45ORIS900245GSC45CoalSteamNoOperationNoOperationSCR SCRNoOperationNoOperationScrubber Scrubber45031GENERIC UNIT900345GSC45ORIS900345GSC45CoalSteamNoOperationNoOperationSCR SCRNoOperationNoOperationScrubber Scrubber45039GENERIC UNIT900445GSC45ORIS900445GSC45CoalSteamNoOperationNoOperationSCR SCRNoOperationNoOperationScrubber Scrubber45043GENERIC UNIT900545GSC45ORIS900545GSC45CoalSteamNoOperationNoOperationCrossUnit 4SCRNoOperationNoOperationCrossUnit 4Scrubber47001TVA BULL RUN FOSSILPLANT3396 1 0009 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber47073TVA JOHN SEVIER FOSSILPLANT3405 1 0007 001CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber47073TVA JOHN SEVIER FOSSILPLANT3405 2 0007 002CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber47073TVA JOHN SEVIER FOSSILPLANT3405 3 0007 003CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber47073TVA JOHN SEVIER FOSSILPLANT3405 4 0007 004CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber47085TVA JOHNSONVILLE FOSSILPLANT3406 1 0011 001CoalSteamNone SCR SCR SCR NoneNone None NoneDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.301APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls47085TVA JOHNSONVILLE FOSSILPLANT3406 2 0011 002CoalSteamNone SCR SCR SCR NoneNone None None47085TVA JOHNSONVILLE FOSSILPLANT3406 3 0011 003CoalSteamNone SCR SCR SCR NoneNone None None47085TVA JOHNSONVILLE FOSSILPLANT3406 4 0011 004CoalSteamNone SCR SCR SCR NoneNone None None47085TVA JOHNSONVILLE FOSSILPLANT3406 5 0011 005CoalSteamNone SCR SCR SCR NoneNone None None47085TVA JOHNSONVILLE FOSSILPLANT3406 6 0011 006CoalSteamNone SCR SCR SCR NoneNone None None47085TVA JOHNSONVILLE FOSSILPLANT3406 7 0011 007CoalSteamNone SCR SCR SCR NoneNone None None47085TVA JOHNSONVILLE FOSSILPLANT3406 8 0011 008CoalSteamNone SCR SCR SCR NoneNone None None47085TVA JOHNSONVILLE FOSSILPLANT3406 9 0011 009CoalSteamNone SCR SCR SCR NoneNone None None47085TVA JOHNSONVILLE FOSSILPLANT3406 10 0011 010CoalSteamNone SCR SCR SCR NoneNone None None47145TVA KINGSTON FOSSILPLANT3407 1 0013 001CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber47145TVA KINGSTON FOSSILPLANT3407 2 0013 002CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber47145TVA KINGSTON FOSSILPLANT3407 3 0013 003CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber47145TVA KINGSTON FOSSILPLANT3407 4 0013 004CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber47145TVA KINGSTON FOSSILPLANT3407 5 0013 005CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber47145TVA KINGSTON FOSSILPLANT3407 6 0013 006CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber47145TVA KINGSTON FOSSILPLANT3407 7 0013 007CoalSteamSCR SCR SCR SCR NoneNone Scrubber Scrubber47145TVA KINGSTON FOSSILPLANT3407 8 0013 008CoalSteamSCR SCR SCR SCR NoneNone Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.302APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls47145TVA KINGSTON FOSSILPLANT3407 9 0013 009CoalSteamSCR None SCR SCR NoneNone Scrubber Scrubber47157 ALLEN FOSSIL PLANT 3393 1 00528 Boilr1CoalSteamSCR SCR SCR SCR NoneNone None None47157 ALLEN FOSSIL PLANT 3393 2 00528 Boilr2CoalSteamSCR SCR SCR SCR NoneNone None None47157 ALLEN FOSSIL PLANT 3393 3 00528 Boilr3CoalSteamSCR SCR SCR SCR NoneNone None None47161TVA CUMBERLAND FOSSILPLANT3399 1 0011 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber47161TVA CUMBERLAND FOSSILPLANT3399 2 0011 002CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber47165TVA GALLATIN FOSSILPLANT3403 1 0025 001CoalSteamNone None None None None None Scrubber Scrubber47165TVA GALLATIN FOSSILPLANT3403 2 0025 002CoalSteamNone None None None None None Scrubber Scrubber47165TVA GALLATIN FOSSILPLANT3403 3 0025 003CoalSteamNone None None None None None Scrubber Scrubber47165TVA GALLATIN FOSSILPLANT3403 4 0025 004CoalSteamNone None None None None None Scrubber Scrubber51031DOMINION - ALTAVISTAPOWER STATION10773 1 00156 1CoalSteamSNCR SNCR SNCR SNCR ScrubberScrubber Scrubber Scrubber51031DOMINION - ALTAVISTAPOWER STATION10773 2 00156 2 0 0 0 0 0 0 0 051041DOMINION - CHESTERFIELDPOWER STATION3797 3 00002 3CoalSteamNone None None None None None Scrubber None51041DOMINION - CHESTERFIELDPOWER STATION3797 4 00002 4CoalSteamSCR None SCR SCR NoneNone Scrubber Scrubber51041DOMINION - CHESTERFIELDPOWER STATION3797 5 00002 6CoalSteamSCR None SCR SCR NoneNone Scrubber Scrubber51041DOMINION - CHESTERFIELDPOWER STATION3797 6 00002 8CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber51065DOMINION - BREMO POWERSTATION3796 3 00001 1CoalSteamNone None None NoneNone None None NoneDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.303APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls51065DOMINION - BREMO POWERSTATION3796 4 00001 2CoalSteamSNCR SNCR SNCR SNCR NoneNone None None51071AMERICAN ELECTRICPOWER GLEN LYN3776 51 00002 1CoalSteamNone None None NoneNone None None None51071AMERICAN ELECTRICPOWER GLEN LYN3776 52 00002 2CoalSteamNone None None NoneNone None None None51071AMERICAN ELECTRICPOWER GLEN LYN3776 6 00002 3CoalSteamNone None None None None None None Scrubber51083DOMINION - CLOVER POWERSTATION7213 1 00046 1CoalSteamSNCR SNCR SNCR SNCR ScrubberScrubber Scrubber Scrubber51083DOMINION - CLOVER POWERSTATION7213 2 00046 2CoalSteamSNCR SNCR SNCR SNCR ScrubberScrubber Scrubber Scrubber51099BIRCHWOOD POWERPARTNERS, L.P.54304 1 00012 1CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber51117Mecklenburg CogenerationFacility52007 GEN1 00051 1CoalSteamNone None None None Scrubber Scrubber Scrubber Scrubber51117Mecklenburg CogenerationFacility52007 GEN2 00051 2CoalSteamNone None None None Scrubber Scrubber Scrubber Scrubber51153 DOMINION - POSSUM POINT 3804 3 00002 3CoalSteamNoneCombined CycleNoneCombined CycleNoneCombined CycleNoneCombined Cycle51153 DOMINION - POSSUM POINT 3804 4 00002 4CoalSteamNoneCombined CycleNoneCombined CycleNoneCombined CycleNoneCombined Cycle51153 DOMINION - POSSUM POINT 3804 5 00002 5 O/G Steam NoneNoOperationNoneNoOperationNoneNoOperationNoneNoOperation51153 DOMINION - POSSUM POINT 3804 6 00002CombinedCycleCombined CycleCombined CycleCombined CycleCombined CycleCombined CycleCombined CycleCombined CycleCombined Cycle51167AMERICAN ELECTRICPOWERCLINCH RIVER PLANT3775 1 00003 1CoalSteamNone None SNCR SCR None NoneEmissionCapScrubber51167AMERICAN ELECTRICPOWERCLINCH RIVER PLANT3775 2 00003 2CoalSteamNone None SNCR SCR None NoneEmissionCapScrubber51167AMERICAN ELECTRICPOWERCLINCH RIVER PLANT3775 3 00003 3CoalSteamNone None SNCR SCR None NoneEmissionCapScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.304APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls51175LG&E WestmorelandSouthampton10774 GEN1 00051 1CoalSteamNone None None None Scrubber Scrubber Scrubber Scrubber51175LG&E WestmorelandSouthampton00051 2 None None None None 0 0 0 051175LG&E WestmorelandSouthampton00051 4 None None None None 0 0 0 051199DOMINION - YORKTOWNPOWER STATION3809 3 00001 3 O/G Steam SNCRNoOperationSNCRNoOperationNoneNoOperationScrubberNoOperation51199DOMINION - YORKTOWNPOWER STATION3809 2 00001 5CoalSteamSNCR SNCR SNCR SNCR NoneNone Scrubber None51199DOMINION - YORKTOWNPOWER STATION3809 1 00001 6CoalSteamSNCR SNCR SNCR SNCR NoneNone Scrubber None51510POTOMAC RIVERGENERATING STATION3788 1 00003 1CoalSteamSNCRCoalEarlyRetirementSNCRCoalEarlyRetirementNoneCoalEarlyRetirementNoneCoalEarlyRetirement51510POTOMAC RIVERGENERATING STATION3788 2 00003 2CoalSteamSNCRCoalEarlyRetirementSNCRCoalEarlyRetirementNoneCoalEarlyRetirementNoneCoalEarlyRetirement51510POTOMAC RIVERGENERATING STATION3788 3 00003 3CoalSteamSNCR None SNCR None None None None None51510POTOMAC RIVERGENERATING STATION3788 4 00003 4CoalSteamSNCR None SNCR None None None None None51510POTOMAC RIVERGENERATING STATION3788 5 00003 5CoalSteamSNCR None SNCR None None None None None51550 DOMINION - CHESAPEAKE 3803 1 00026 1CoalSteamSNCR SNCR SNCR SNCRLow SCoalNone Scrubber None51550 DOMINION - CHESAPEAKE 3803 2 00026 2CoalSteamSNCR SNCR SNCR SNCRLow SCoalNone Scrubber None51550 DOMINION - CHESAPEAKE 3803 3 00026 3CoalSteamSCR None SCR SCRLow SCoalNone Scrubber Scrubber51550 DOMINION - CHESAPEAKE 3803 4 00026 4CoalSteamSCR None SCR SCRLow SCoalNone Scrubber Scrubber51159GENERIC UNIT900151GSC51ORIS900151GSC51CoalSteamNoOperationNoOperationSCR SCRNoOperationNoOperationScrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.305APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls51167GENERIC UNIT900251GSC51ORIS900251GSC51CoalSteamNoOperationNoOperationSCR SCRNoOperationNoOperationScrubber Scrubber51195GENERIC UNIT900251GSC51ORIS900251GSC51CoalSteamNoOperationNoOperationSCR SCRNoOperationNoOperationScrubber Scrubber51175GENERIC UNIT900351GSC51ORIS900351GSC51CoalSteamNoOperationNoOperationSCR SCRNoOperationNoOperationScrubber Scrubber51175GENERIC UNIT900451GSC51ORIS900451GSC51CoalSteamNoOperationNoOperationSCR SCRNoOperationNoOperationScrubber Scrubber51181GENERIC UNIT900551GSC51ORIS900551GSC51CoalSteamNoOperationNoOperationSCR SCRNoOperationNoOperationScrubber Scrubber54023MOUNT STORM POWERPLANT3954 1 0003 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54023MOUNT STORM POWERPLANT3954 2 0003 002CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54023MOUNT STORM POWERPLANT3954 3 0003 003CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54023NORTH BRANCH POWERSTATION7537 1A 0014 001CoalSteamNone None None NoneNone None None None54023NORTH BRANCH POWERSTATION7537 1B 0014 002CoalSteamNone None None NoneNone None None None54025WESTERNGREENBRIER00066 GEN1CoalSteamNoOperationNoOperationSCRNoOperationNoOperationNoOperationSCRNoOperation54033MONONGAHELA POWER COHARRISON3944 1 0015 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54033MONONGAHELA POWER COHARRISON3944 2 0015 002CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54033MONONGAHELA POWER COHARRISON3944 3 0015 003CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54039APPALACHIAN POWERKANAWHA RIVER PLANT3936 1 0006 001CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber54039APPALACHIAN POWERKANAWHA RIVER PLANT3936 2 0006 002CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber54049MONONGAHELA POWER CO.RIVESVILLE POWER3945 7 0009 001CoalSteamNoneCoalEarlyNoneCoalEarlyNoneCoalEarlyCoalEarlyCoalEarlyDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.306APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018ControlsRetirementRetirementRetirementRetirementRetirement54049MONONGAHELA POWER CO.RIVESVILLE POWER3945 8 0009 002CoalSteamNoneCoalEarlyRetirementNoneCoalEarlyRetirementNoneCoalEarlyRetirementCoalEarlyRetirementCoalEarlyRetirement54049AMERICAN BITUMINOUSPOWERGRANT TOWN PLT10151 0026 001 None None None None Scrubber Scrubber Scrubber Scrubber54049GRANT TOWN POWERPLANT10151 GEN1 ORIS10151 GEN1CoalSteamSNCR None None None Scrubber Scrubber Scrubber Scrubber54051OHIO POWERMITCHELL PLANT3948 1 0005 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54051OHIO POWERMITCHELL PLANT3948 2 0005 002CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54051OHIO POWERKAMMER PLANT3947 1 0006 001CoalSteamNone SCR SCR SCR NoneScrubber Scrubber Scrubber54051OHIO POWERKAMMER PLANT3947 2 0006 002CoalSteamNone SCR SCR SCR NoneScrubber Scrubber Scrubber54051OHIO POWERKAMMER PLANT3947 3 0006 003CoalSteamNone SCR SCR SCR NoneScrubber Scrubber Scrubber54053APPALACHIAN POWER CO.PHILIP SPORN PLANT3938 11 0001 001CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber54053APPALACHIAN POWER CO.PHILIP SPORN PLANT3938 21 0001 002CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber54053APPALACHIAN POWER CO.PHILIP SPORN PLANT3938 31 0001 003CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber54053APPALACHIAN POWER CO.PHILIP SPORN PLANT3938 41 0001 004CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber54053APPALACHIAN POWER CO.PHILIP SPORN PLANT3938 51 0001 005CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber54053APPALACHIAN POWERMOUNTAINEER PLANT6264 1 0009CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54061MONONGAHELA POWER CO.FORT MARTIN POWER3943 1 0001 001CoalSteamSNCR SNCR SNCR SNCR NoneNone Scrubber ScrubberDocumentation of the Base G2 and Best & Final 2002 Base Year, 2009 and 2018 Emission InventoriesAppendix IMACTEC, Inc.307APPENDIX I: EGU CONTROLS FOR COAL AND OIL/GAS UNITS FOR THE B&F INVENTORYPost-Combustion ControlsFIPSFacility NameORISIDBLRIDSITEIDUNITIDPlantTypeVISTASNOx2009ControlsIPMNOx2009ControlsVISTASNOx2018ControlsIPMNOx2018ControlsVISTASSO2 2009ControlsIPMSO2 2009ControlsVISTASSO2 2018ControlsIPMSO2 2018Controls54061MONONGAHELA POWER CO.FORT MARTIN POWER3943 2 0001 002CoalSteamSNCR SNCR SNCR SNCR NoneNone Scrubber Scrubber54061MORGANTOWN ENERGYASSOCIATES0027 043 None None NoneNone None None None None54061MORGANTOWN ENERGYFACILITY10743 GEN1 ORIS10743 GEN1CoalSteamNone None None NoneNone None None None54061LONGVIEW00134 GEN1CoalSteamNoOperationNoOperationSCRNoOperationNoOperationNoOperationScrubberNoOperation54061GENERIC UNIT900154GSC54ORIS900154GSC54CoalSteamNoOperationNoOperationNoOperationSCRNoOperationNoOperationNoOperationScrubber54073MONONGAHELA POWER CO.WILLOW ISLAND3946 1 0004 001CoalSteamNoneCoalEarlyRetirementNoneCoalEarlyRetirementNoneCoalEarlyRetirementCoalEarlyRetirementCoalEarlyRetirement54073MONONGAHELA POWER CO.WILLOW ISLAND3946 2 0004 002CoalSteamNone SCR SCR SCR NoneScrubber Scrubber Scrubber54073MONONGAHELA POWER COPLEASANTS POWERSTATION6004 1 0005 001CoalSteamSCR SCR SCR SCRScrubberUpgradeScrubberScrubberUpgradeScrubber54073MONONGAHELA POWER COPLEASANTS POWERSTATION6004 2 0005 002CoalSteamSCR SCR SCR SCRScrubberUpgradeScrubberScrubberUpgradeScrubber54077MONONGAHELA POWER COALBRIGHT3942 1 0001 001CoalSteamNoneCoalEarlyRetirementCoalEarlyRetirementCoalEarlyRetirementNoneCoalEarlyRetirementCoalEarlyRetirementCoalEarlyRetirement54077MONONGAHELA POWER COALBRIGHT3942 2 0001 002CoalSteamNoneCoalEarlyRetirementCoalEarlyRetirementCoalEarlyRetirementNoneCoalEarlyRetirementCoalEarlyRetirementCoalEarlyRetirement54077MONONGAHELA POWER COALBRIGHT3942 3 0001 003CoalSteamNone None SCR SCR NoneNone Scrubber Scrubber54079APPALACHIAN POWERJOHN E AMOS PLANT3935 1 0006 001CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54079APPALACHIAN POWERJOHN E AMOS PLANT3935 2 0006 002CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber54079APPALACHIAN POWERJOHN E AMOS PLANT3935 3 0006 003CoalSteamSCR SCR SCR SCR ScrubberScrubber Scrubber Scrubber

# Weight of Evidence

E2: TSD Version IV 042508

“With CAIR”

Link to:

http://www.epa.ohio.gov/port als/27/SIP/Attain/E2_TSD_Vers ion_IV_April_25_2008_FINAL.pdf

# Regional Air Quality Analyses for

Ozone, PM 2. 5 

# , and Regional Haze:

F inal Technical Support Document

April 25 , 2008

States of Illinois, Indiana, Michigan, Ohio, and Wisconsin

# ii 

# Table of Contents

Section

- Title Pa ge

Executive Summary i i i

1

. 0 Introduction 1

1

. 1 SIP Requirements 1

1

. 2 Organization 2

1

. 3 Technical Work: Overview 3

2

. 0 Ambient Data Analyses 4

2

. 1 Ozone 4

2

. 2 PM 2. 5 

# 2 1

2

. 3 Regional Haze 35

3

. 0 Air Quality Model ing 4 6

3

. 1 Selection of Base Year 46

3

. 2 Future Years of Interest 46

3

. 3 Modeling System 4 7

3

. 4 Domain/Grid Resolution 47

3

. 5 Model Inputs: Meteorology 48

3

. 6 Model Inputs: Emissions 51

3

. 7 Base Year Modeling Results 60

4

. 0 Attainment De monstration for Ozone and PM 2.5 

# 7 1

4

. 1 Future Year Modeling Results 71

4

. 2 Supplemental Analyses 82

4

. 3 Weight of Evidence Determination for Ozone 82

4

. 4 Weight of Evidence Determination for PM 2. 5 

# 90

5

. 0 Reasonable Progress Assessment for Regional Haze 9 3

5

. 1 Class I Areas Impacted 93

5

. 2 Future Year Modeling Results 96

5

. 3 Weight of Evidence Determination for Regional Haze 1 04

6

. 0 Summary 1 11

7

. 0 References 1 1 4

Appendix I Ozone and PM 2.5 

# Modeling Results

Appendix II Ozone Source Apportio nment Modeling Results

Appendix III PM 2.5 

# Source Apportionment Modeling Results

Appendix IV Haze Source Apportionment Modeling Results

# iii 

# EXECUTIVE SUMMARY

States in the upper Midwest face a number of air quality challenges. More than 5 0 counties are

cu rrently classified as nonattainment for the 8

- hour ozone standard and 60 for the f ine particle

( PM 2.5 

# ) standard (1997 version s ). A map of these nonattainment areas is provided in the figure

below. In addition, visibility impairment due to regional haze is a problem in the larger national

parks and wilderness areas (i.e., Class I areas). There are 156 Class I areas in the U.S.,

including two in northern Michigan

.

Figure i

. Current nonattainment counties for ozone (left) and PM 2. 5 

# (right )



# T o support the development of State Implementation Plans (SIPs) for ozone, PM 2.5 

# , and

regional haze in the States of Illinois, Indiana, Michigan, Ohio, and Wisconsin, technical

analyses were conducted by the Lake Michigan Air Directors Consortium (LADCO ), its member

states, and various contractors

. The analyses include preparation of regional emissions

inventories and meteorological data, evaluation and application of regional chemical transport

models, and collection and analysis of ambient monitoring data.

M onitoring data were analyzed to produce a conceptual understanding of the air quality

problems. Key findings of the analyses include:

Ozone

• Current monitoring data (2005

- 2007) show about 20 sites in violation of the 8

- hour

ozone standard of 85 parts per billion (ppb) . Historical ozone data show a steady

downward trend over the past 15 years, especially since 2001

- 2003, due likely t o federal and state emission control programs.

• Ozone concentrations are strongly influenced by meteorological con ditions, with

more high ozone days and higher ozone levels during summers with above normal

temperatures.

# iv



# • Inter

- and intra

- regional t ransport of ozone and ozone precursors aff ects many

portions of the five states , and is the principal cause of nonattainme nt in some areas

far from population or industrial centers

.

PM 2.5



# • Current monitoring data (200 5

- 200 7 ) show 3 0 sites in violation of the annual PM 2.5



# standard of 15 ug/m 3



# . N onattainment sites are characterized by an elevated

regional background ( about 12

– 14 ug/m 3 

# ) and a significant local (urban) increment

( about 2

– 3 ug/m 3 

# ). Historical PM 2.5 

# data show a slight downward trend since

deployment of the PM 2.5 

# monitoring network in 1999.

• PM 2.5 

# concentrations are also influenced by meteorology , but the re lationship is

more complex and less well understood compared to ozone.

• O n an annual average basis, PM 2.5 

# chemical composition consists mostly of sulfate,

nitrate, and organic carbon in similar proportions.

Haze

• Current monitoring data (2000

- 2004) show visibility levels in the Class I areas in

northern Michigan are on the order of 2 2

– 2 4 deciviews . The goal of EPA’s visibility

program is to achieve natural conditions, which is about 12 deciviews for these

Class I areas, by the year 2064.

• Visibility im pairment is dominated by sulfate and nitrate.

Air quality models were applied to s upport the regional planning efforts

. Two base years were

used in the modeling analyses: 2002 and 2005. B asecase modeling was conducted to evaluate

model performance (i.e., assess the model's ability to reproduce observed concentrations ) . This

exercise wa s intended to build confidence in the model prior to its use in examining co ntrol

strategies. M odel performance for ozone and PM 2.5 

# was found to be generally acceptable.

Future year strategy modeling was conducted to determine whether existing (“on the books”)

controls would be sufficient to provide for attainment of the standards for ozone and PM 2.5 

# and if

not, then what additional emission reductions would be necessary f or attainment. Based on th e

modeling and other supplemental analyses , the following general conclusions can be made:

• E xisting controls are expected to produce significant improvement in ozone and



# PM 2.5 

# concentrations and visibility levels

.

• The choice of

the base year affects the future year model projections. A key

difference between the base years of 2002 and 2005 is meteorology. 2002 was

more ozone conducive than 2005. The choice of which base year to use as the

basis for the SIP is a policy decisio n (i.e., how much safeguard to incorporate).

• M odeling suggests that mo st sites are expected to meet the current 8

- hour ozone

standard by the applicable attainment date, except for sites in western Michigan

and, possibly, in eastern Wisconsin a nd northeast ern Ohio.

# v



# • Modeling suggests that m ost sites a re expected to meet the current PM 2.5 

# standard by the applicable attainment date, except for sites in Detroit, Cleveland,

and Granite City

.

T he regiona l modeling for PM 2.5 

# does not include air quality benefit s expected

from local controls. States are conducting local

- scale analyses and will us e

these results, in conjunction with the regional

- scale modeling, to support their

attainment demonstrations for PM 2.5



# .

• These findings of residual nonattainment for ozon e and PM 2.5 

# are supported by

current (2005

– 2007) monitoring data which show significant nonattainment in

the region (e.g., peak ozone design values on the order of 90

– 93 ppb, and peak

PM 2.5 

# d esign values on the order of 16

- 17 ug/m 3 

# ). It is unlikely that sufficient

emission reductions will occur in the next couple of years to provide for

attainment at all sites.

• Attainment at most sites by the applicable attainment date is dependent on actual

future year meteorology (e.g., if the weather conditions a re consistent with [or

less severe than] 2005, then attainment is likely) and actual future year

emissions (e.g., if the emission reductions associated with the existing controls

are achieved, then attainment is likely). I f either of these conditions is n ot met,

then attainment may be less likely.

• M ode ling s uggests that the new PM 2.5 

# 24

- hour standard and the new lower

ozone standard will not be met at several sites , even by 2018, with existing

controls.

• Visibility levels in a few Class I areas in the eas tern U.S. are expected to be

greater than

(less improved than) the uniform rate of visibility improvement

value s in 2018 based on existing controls , including those in northern Michigan

and s ome in the northeastern U.S. Visibility levels in m any other Cla ss I areas in

the eastern U.S. are expected to be less than (more improved than) the uniform

rate of visibility improvement value s in 2018. These results, along with

information on the costs of compliance, time necessary for compliance, energy

and non air

quality environmental impacts of compliance, and remaining useful

life of existing sources, should be considered by the states in setting reasonable

progress goals for regional haze.

# 1 

# Section 1. 0 Introduction

This Technical Support Document summarizes the final air quality analyses conducted by the

Lake Michigan Directors Consortium (LADCO) 1 

# and its contractors to support the development

of State Implementation Plans (SIPs) for ozone, fine particles ( PM 2.5 

# ), and regional haze in the

States of Illinois, Indiana, Michigan, Ohio, and Wisconsin

. The analyses include preparation of

regional emissions inventories and meteorological modeling data for two base years (2002 and

2005), evaluation and application of regional chemical transport models, and analysis of

ambient monitoring data.

Two aspects of the analyses should be emphasize d. First, a regional , multi

- pollutant approach

was taken in addressing ozone, PM 2.5 

# , and haze f or technical reasons (e.g., common ality in

precursors, emission sources, atmosphe ric processes, transport influences, and geographic

areas of concern), and practical reasons (e.g., more efficient use of program resources).

Furthermore, EPA has consistently encouraged multi

- pollutant planning in its rule for the haze

program (64 FR 357 19), and its implementation guidance for ozone (70 FR 71663) and PM 2.5 

# (72 FR 20609). Second, a weight

- of

- evidence approach was taken in considering the results of

the various analyses (i.e., two sets of modeling results

-- one for a 2002 base year and on e for a

2005 base year

-- and ambient data analyses) in order to provide a more robust assessment of

expected future year air quality.

The report is orga nized in the following sections. This I ntroduction p rovides an overview of

regulatory requirements and background information on regional planning . Section 2 r eviews

the ambient monitoring data and presents a conceptual model of ozone, PM 2.5 

# , and haze for the

region . Section 3 d iscusses the air quality modeling analyses, including development of the k ey model inputs (emissions inventory and meteorological data), and basecase model performance

evaluation . A modeled a ttainment d emonstration for o zone and PM 2.5 

# is presented in Section 4,

along with relevant data analyses considered as part of the weight

- of

- evidence de termination

. Section 5 documents the r easonable p rogress a ssessment for r egional h aze

, a long with

relevant data analyses considered as part of the weight

- of

- evidence determination . Finally, ke y study findings are reviewed and summarized in Section 6.

1.1 SIP Requirements

For ozone, EPA promulgated designations on April 15, 2004 (69 FR 23858, April 30, 2004). In

the 5

- state region, m ore than 100 counties were designated as nonattainment

. 2 

# The

designations became effective on June 15, 2004. SIPs for ozone we re due no later than three

years from the effective date of the nonattainment designations (i.e., by June 2007). The

attainment date for ozone varies as a function of nonattainment classification. For the region,

the attainment dates a re either June 2007 (marginal nonattainment areas), June 2009 (basic

nonattainment areas), or June 2010 (moderate nonattainment areas).

1 

# A sub

- entity of LADCO, known as the Midwest Regional Planning Organization (MRPO), is responsible

for the regional haze activities of the multi

- state organization.

2 

# Based on more recent air quality data, many counties in Indiana, Michigan, and Ohio were

subsequently redesignated as attainment. As of December 31 , 2007, there are 53 counties designated

as n onattainment in the region.

# 2



# For PM 2.5 

# , EPA promulgated designations on December 17, 2004 (70 FR 944, January 5, 2005).

In the 5

- state region, 70 c ounties were designated as nonattainment. 3 

# The designations bec a me

effective on April 5, 2005. SIPs for PM 2.5 

# are due no later than three years from the effective

date of the nonattainment designations (per section 172(b) of the Clean Air Act) (i.e., by A pril

2008) and for haze no later than three years after the date on which the Administrator

promulgate d the PM 2.5 

# designations (per the Omnibus Appropriations Act of 2004) (i.e., by

December 2007). The applicable attainment date for PM 2.5 

# nonattainment ar eas is five years

from the date of the nonattainment designation (i.e., by April 2010).

For haze, the Clean Air Act sets “as a national goal the prevention of any future, and the

remedying of any existing, impairment of visibility in Class I ar eas which impairment results from

manmade air pollution.” T here are 156 Class I areas, including two in northern Michigan: Isle

Royale National Park and Seney National Wildlife Refuge 4



# . EPA’s visibility rule (64 FR 35714,

July 1, 1999) require s reasonabl e progress in achieving “natural conditions” by the year 2064.

As noted above, the first regional haze SIP wa s due in December 2007 and must address the

initial 10

- year implementation period (i.e., reasonable progress by the year 2018). SIP

requirements (pursuant to 40 CFR 51.308(d)) include setting reasonable progress goals,

determining baseline conditions, determining natural conditions, providing a long

- term control

strategy, providing a monitoring strategy (air quality and emissions), and establishing BART

emissions limitations and associated compliance schedule.

1.2 Organization

LADCO wa s established by the States of Illinois, Indiana, Michigan, and Wisconsin in 1989. T he

four states and EPA signed a Memorandum of Agreement (MOA) that initiated t he Lake

Michigan Ozone Study (LMOS) and identified LADCO as the organization to oversee th e study.

Additional MOAs were signed by the States in 1991 (to establish the Lake Michigan Ozone

Control Program)

, January 2000 (to broaden LADCO’s responsibilities) , and June 2004 (to

update LADCO’s mission and reaffirm the commitment to regional planning). In March 2004,

Ohio joined LADCO. LADCO consists of a Board of Directors (i.e., the State Air Directors), a

technical staff, and various workgroups. The main p urpose s of LADCO are to provide technical

assessments for and assistance to its member states

, and to provide a forum for its member

states to discuss regional air quality issues.

MRPO is a similar entity led by the five LADCO States and involves the fe derally recognized

tribes in Michigan and Wisconsin

, EPA

, and Federal Land Managers (i.e., National Park

Service, U.S. Fish & Wildlife Agency, and U.S. Forest Service )

. In October 2000, the States of

Illinois, Indiana, Michigan, Ohio, and Wisconsin signed a n MOA that established the MRPO. An

o perating principles document for M RPO, which describe the roles and responsibilities of states,

tribes, federal agencies, and stakeholders, w as issued in March 2001

. M RPO has a similar

purpose as LADCO , but is focus ed on visibility impairment due to regional haze in the Federal

Class I areas located inside the borders of the five states, and the impact of emissions from the

five states on visibility impairment due to regional haze in the Federal Class I areas located

outside the borders of the five states. MRPO works cooperatively with the R egional Planning

Organizations (R POs ) representing other parts of the country. The RPOs sponsored several

3 

# USEPA subsequently adjusted the final designations, which resulted in 63 counties in the region being

designate d as nonattainment (70 FR 19844, April 15, 2005)

.

4 

# Although Rainbow Lake in northern Wisconsin is also a Class I area, the visibility rule does not apply

because the Federal Land Manager determined that visibility is not an air quality related value there

.